10-Q

__________________________________________________________________________________________

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)
☑	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2022

OR

☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to ____________

Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.	Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.
1-11299	ENTERGY CORPORATION	1-35747	ENTERGY NEW ORLEANS, LLC
	(a Delaware corporation) 639 Loyola Avenue New Orleans, Louisiana 70113 Telephone (504) 576-4000		(a Texas limited liability company) 1600 Perdido Street New Orleans, Louisiana 70112 Telephone (504) 670-3700
	72-1229752		82-2212934
1-10764	ENTERGY ARKANSAS, LLC	1-34360	ENTERGY TEXAS, INC.
	(a Texas limited liability company) 425 West Capitol Avenue Little Rock, Arkansas 72201 Telephone (501) 377-4000		(a Texas corporation) 2107 Research Forest Drive The Woodlands, Texas 77380 Telephone (409) 981-2000
	83-1918668		61-1435798
1-32718	ENTERGY LOUISIANA, LLC	1-09067	SYSTEM ENERGY RESOURCES, INC.
	(a Texas limited liability company) 4809 Jefferson Highway Jefferson, Louisiana 70121 Telephone (504) 576-4000		(an Arkansas corporation) 1340 Echelon Parkway Jackson, Mississippi 39213 Telephone (601) 368-5000
	47-4469646		72-0752777
1-31508	ENTERGY MISSISSIPPI, LLC
	(a Texas limited liability company) 308 East Pearl Street Jackson, Mississippi 39201 Telephone (601) 368-5000
	83-1950019

__________________________________________________________________________________________

Securities registered pursuant to Section 12(b) of the Act:

Registrant	Title of Class	Trading Symbol	Name of Each Exchange on Which Registered
Entergy Corporation	Common Stock, $0.01 Par Value	ETR	New York Stock Exchange
	Common Stock, $0.01 Par Value	ETR	NYSE Chicago, Inc.
Entergy Arkansas, LLC	Mortgage Bonds, 4.875% Series due September 2066	EAI	New York Stock Exchange
Entergy Louisiana, LLC	Mortgage Bonds, 4.875% Series due September 2066	ELC	New York Stock Exchange
Entergy Mississippi, LLC	Mortgage Bonds, 4.90% Series due October 2066	EMP	New York Stock Exchange
Entergy New Orleans, LLC	Mortgage Bonds, 5.0% Series due December 2052	ENJ	New York Stock Exchange
	Mortgage Bonds, 5.50% Series due April 2066	ENO	New York Stock Exchange
Entergy Texas, Inc.	5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)	ETI/PR	New York Stock Exchange

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes ☑ No ☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files).  Yes ☑ No ☐

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.

	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
Entergy Corporation	ü
Entergy Arkansas, LLC			ü
Entergy Louisiana, LLC			ü
Entergy Mississippi, LLC			ü
Entergy New Orleans, LLC			ü
Entergy Texas, Inc.			ü
System Energy Resources, Inc.			ü

If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑

Common Stock Outstanding		Outstanding at April 29, 2022
Entergy Corporation	($0.01 par value)	203,374,308

Entergy Corporation, Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc. separately file this combined Quarterly Report on Form 10-Q.  Information contained herein relating to any individual company is filed by such company on its own behalf.  Each company reports herein only as to itself and makes no other representations whatsoever as to any other company.  This combined Quarterly Report on Form 10-Q supplements and updates the Annual Report on Form 10-K for the calendar year ended December 31, 2021, filed by the individual registrants with the SEC, and should be read in conjunction therewith.

TABLE OF CONTENTS

	Page Number
Forward-looking Information	iii
Definitions	vi
Part I. Financial Information
Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis	1
Consolidated Income Statements	15
Consolidated Statements of Comprehensive Income	17
Consolidated Statements of Cash Flows	18
Consolidated Balance Sheets	20
Consolidated Statements of Changes in Equity	22
Notes to Financial Statements
Note 1. Commitments and Contingencies	23
Note 2. Rate and Regulatory Matters	24
Note 3. Equity	32
Note 4. Revolving Credit Facilities, Lines of Credit, Short-term Borrowings, and Long-term Debt	36
Note 5. Stock-based Compensation	41
Note 6. Retirement and Other Postretirement Benefits	43
Note 7. Business Segment Information	46
Note 8. Risk Management and Fair Values	48
Note 9. Decommissioning Trust Funds	64
Note 10. Income Taxes	70
Note 11. Property, Plant, and Equipment	70
Note 12. Variable Interest Entities	71
Note 13. Revenue	72
Item 3. Quantitative and Qualitative Disclosures About Market Risk	75
Item 4. Controls and Procedures	75
Entergy Arkansas, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	76
Consolidated Income Statements	83
Consolidated Statements of Cash Flows	85
Consolidated Balance Sheets	86
Consolidated Statements of Changes in Member’s Equity	88
Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	89
Consolidated Income Statements	97

i

TABLE OF CONTENTS

	Page Number
Consolidated Statements of Comprehensive Income	98
Consolidated Statements of Cash Flows	99
Consolidated Balance Sheets	100
Consolidated Statements of Changes in Equity	102
Entergy Mississippi, LLC
Management’s Financial Discussion and Analysis	103
Income Statements	109
Statements of Cash Flows	111
Balance Sheets	112
Statements of Changes in Member’s Equity	114
Entergy New Orleans, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	115
Consolidated Income Statements	121
Consolidated Statements of Cash Flows	123
Consolidated Balance Sheets	124
Consolidated Statements of Changes in Member’s Equity	126
Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis	127
Consolidated Income Statements	134
Consolidated Statements of Cash Flows	135
Consolidated Balance Sheets	136
Consolidated Statements of Changes in Equity	138
System Energy Resources, Inc.
Management’s Financial Discussion and Analysis	139
Income Statements	146
Statements of Cash Flows	147
Balance Sheets	148
Statements of Changes in Common Equity	150
Part II. Other Information
Item 1. Legal Proceedings	151
Item 1A. Risk Factors	151
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	152
Item 5. Other Information	152
Item 6. Exhibits	154
Signature	156

ii

FORWARD-LOOKING INFORMATION

In this combined report and from time to time, Entergy Corporation and the Registrant Subsidiaries each makes statements as a registrant concerning its expectations, beliefs, plans, objectives, goals, projections, strategies, and future events or performance.  Such statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995.  Words such as “may,” “will,” “could,” “project,” “believe,” “anticipate,” “intend,” “expect,” “estimate,” “continue,” “potential,” “plan,” “predict,” “forecast,” and other similar words or expressions are intended to identify forward-looking statements but are not the only means to identify these statements.  Although each of these registrants believes that these forward-looking statements and the underlying assumptions are reasonable, it cannot provide assurance that they will prove correct.  Any forward-looking statement is based on information current as of the date of this combined report and speaks only as of the date on which such statement is made.  Except to the extent required by the federal securities laws, these registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

Forward-looking statements involve a number of risks and uncertainties.  There are factors that could cause actual results to differ materially from those expressed or implied in the forward-looking statements, including (a) those factors discussed or incorporated by reference in Item 1A. Risk Factors in the Form 10-K and in this report, (b) those factors discussed or incorporated by reference in Management’s Financial Discussion and Analysis in the Form 10-K and in this report, and (c) the following factors (in addition to others described elsewhere in this combined report and in subsequent securities filings):

•resolution of pending and future rate cases and related litigation, formula rate proceedings and related negotiations, including various performance-based rate discussions, Entergy’s utility supply plan, and recovery of fuel and purchased power costs, as well as delays in cost recovery resulting from these proceedings;

•regulatory and operating challenges and uncertainties and economic risks associated with the Utility operating companies’ participation in MISO, including the benefits of continued MISO participation, the effect of current or projected MISO market rules and market and system conditions in the MISO markets, the allocation of MISO system transmission upgrade costs, the MISO-wide base rate of return on equity allowed or any MISO-related charges and credits required by the FERC, and the effect of planning decisions that MISO makes with respect to future transmission investments by the Utility operating companies;

•changes in utility regulation, including with respect to retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, and the application of more stringent return on equity criteria, transmission reliability requirements or market power criteria by the FERC or the U.S. Department of Justice;

•changes in the regulation or regulatory oversight of Entergy’s owned or operated nuclear generating facilities and nuclear materials and fuel, including with respect to the planned shutdown and sale of Palisades, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and fuel;

•resolution of pending or future applications, and related regulatory proceedings and litigation, for license modifications or other authorizations required of nuclear generating facilities and the effect of public and political opposition on these applications, regulatory proceedings, and litigation;

•the performance of and deliverability of power from Entergy’s generation resources, including the capacity factors at Entergy’s nuclear generating facilities;

•increases in costs and capital expenditures that could result from changing regulatory requirements, changing economic conditions, and emerging operating and industry issues, and the risks related to recovery of these costs and capital expenditures from Entergy’s customers (especially in an increasing cost environment);

•the commitment of substantial human and capital resources required for the safe and reliable operation and maintenance of Entergy’s nuclear generating facilities;

iii

FORWARD-LOOKING INFORMATION (Continued)

•Entergy’s ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities;

•the prices and availability of fuel and power Entergy must purchase for its Utility customers, and Entergy’s ability to meet credit support requirements for fuel and power supply contracts;

•volatility and changes in markets for electricity, natural gas, uranium, emissions allowances, and other energy-related commodities, and the effect of those changes on Entergy and its customers;

•changes in law resulting from federal or state energy legislation or legislation subjecting energy derivatives used in hedging and risk management transactions to governmental regulation;

•changes in environmental laws and regulations, agency positions or associated litigation, including requirements for reduced emissions of sulfur dioxide, nitrogen oxide, greenhouse gases, mercury, particulate matter and other regulated air emissions, heat and other regulated discharges to water, requirements for waste management and disposal and for the remediation of contaminated sites, wetlands protection and permitting, and changes in costs of compliance with environmental laws and regulations;

•changes in laws and regulations, agency positions, or associated litigation related to protected species and associated critical habitat designations;

•the effects of changes in federal, state, or local laws and regulations, and other governmental actions or policies, including changes in monetary, fiscal, tax, environmental, trade/tariff, domestic purchase requirements, or energy policies and related laws, regulations, and other governmental actions;

•the effects of full or partial shutdowns of the federal government or delays in obtaining government or regulatory actions or decisions;

•uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal and the level of spent fuel and nuclear waste disposal fees charged by the U.S. government or other providers related to such sites;

•variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes (including from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Hurricane Ida), ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance, as well as any related unplanned outages;

•effects of climate change, including the potential for increases in extreme weather events and sea levels or coastal land and wetland loss;

•the risk that an incident at any nuclear generation facility in the U.S. could lead to the assessment of significant retrospective assessments and/or retrospective insurance premiums as a result of Entergy’s participation in a secondary financial protection system and a utility industry mutual insurance company;

•changes in the quality and availability of water supplies and the related regulation of water use and diversion;

•Entergy’s ability to manage its capital projects, including completion of projects timely and within budget and to obtain the anticipated performance or other benefits, and its operation and maintenance costs;

•the effects of supply chain disruptions, including those driven by the COVID-19 global pandemic or by trade-related governmental actions, on Entergy’s ability to complete its capital projects in a timely and cost-effective manner;

•Entergy’s ability to purchase and sell assets at attractive prices and on other attractive terms;

•the economic climate, and particularly economic conditions in Entergy’s Utility service area and events and circumstances that could influence economic conditions in those areas, including power prices and inflation, and the risk that anticipated load growth may not materialize;

•changes to federal income tax laws and regulations, including the continued impact of the Tax Cuts and Jobs Act and its intended and unintended consequences on financial results and future cash flows;

•the effects of Entergy’s strategies to reduce tax payments;

•changes in the financial markets and regulatory requirements for the issuance of securities, particularly as they affect access to capital and Entergy’s ability to refinance existing securities and fund investments and acquisitions;

iv

FORWARD-LOOKING INFORMATION (Concluded)

•actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies’ ratings criteria;

•changes in inflation and interest rates;

•the effects of litigation and government investigations or proceedings;

•changes in technology, including (i) Entergy’s ability to implement new or emerging technologies, (ii) the impact of changes relating to new, developing, or alternative sources of generation such as distributed energy and energy storage, renewable energy, energy efficiency, demand side management and other measures that reduce load and government policies incentivizing development of the foregoing, and (iii) competition from other companies offering products and services to Entergy’s customers based on new or emerging technologies or alternative sources of generation;

•Entergy’s ability to effectively formulate and implement plans to reduce its carbon emission rate and aggregate carbon emissions, including its commitment to achieve net-zero carbon emissions by 2050, and the potential impact on its business of attempting to achieve such objectives;

•the effects, including increased security costs, of threatened or actual terrorism, cyber-attacks or data security breaches, natural or man-made electromagnetic pulses that affect transmission or generation infrastructure, accidents, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;

•the effects of a global or geopolitical event or pandemic, such as the COVID-19 global pandemic and the military activities between Russia and Ukraine, including economic and societal disruptions; volatility in the capital markets (and any related increased cost of capital or any inability to access the capital markets or draw on available bank credit facilities); reduced demand for electricity, particularly from commercial and industrial customers; increased or unrecoverable costs; supply chain, vendor, and contractor disruptions; delays in completion of capital or other construction projects, maintenance, and other operations activities, including prolonged or delayed outages; impacts to Entergy’s workforce availability, health, or safety; increased cybersecurity risks as a result of many employees telecommuting; increased late or uncollectible customer payments; regulatory delays; executive orders affecting, or increased regulation of, Entergy’s business; changes in credit ratings or outlooks as a result of any of the foregoing; or other adverse impacts on Entergy’s ability to execute on its business strategies and initiatives or, more generally, on Entergy’s results of operations, financial condition, and liquidity;

•Entergy’s ability to attract and retain talented management, directors, and employees with specialized skills;

•Entergy’s ability to attract, retain, and manage an appropriately qualified workforce;

•changes in accounting standards and corporate governance;

•declines in the market prices of marketable securities and resulting funding requirements and the effects on benefits costs for Entergy’s defined benefit pension and other postretirement benefit plans;

•future wage and employee benefit costs, including changes in discount rates and returns on benefit plan assets;

•changes in decommissioning trust fund values or earnings or in the timing of, requirements for, or cost to decommission Entergy’s nuclear plant sites and the implementation of decommissioning of such sites following shutdown;

•the decision to cease merchant power generation at all Entergy Wholesale Commodities nuclear power plants by mid-2022, including the implementation of the planned shutdown and sale of Palisades;

•the effectiveness of Entergy’s risk management policies and procedures and the ability and willingness of its counterparties to satisfy their financial and performance commitments; and

•Entergy and its subsidiaries’ ability to successfully execute on their business strategies, including their ability to complete strategic transactions that they may undertake.

v

DEFINITIONS

Certain abbreviations or acronyms used in the text and notes are defined below:

Abbreviation or Acronym	Term
ALJ	Administrative Law Judge
ANO 1 and 2	Units 1 and 2 of Arkansas Nuclear One (nuclear), owned by Entergy Arkansas
APSC	Arkansas Public Service Commission
ASU	Accounting Standards Update issued by the FASB
Board	Board of Directors of Entergy Corporation
Cajun	Cajun Electric Power Cooperative, Inc.
capacity factor	Actual plant output divided by maximum potential plant output for the period
City Council	Council of the City of New Orleans, Louisiana
COVID-19	The novel coronavirus disease declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention in March 2020
D.C. Circuit	U.S. Court of Appeals for the District of Columbia Circuit
DOE	United States Department of Energy
Entergy	Entergy Corporation and its direct and indirect subsidiaries
Entergy Corporation	Entergy Corporation, a Delaware corporation
Entergy Gulf States, Inc.	Predecessor company for financial reporting purposes to Entergy Gulf States Louisiana that included the assets and business operations of both Entergy Gulf States Louisiana and Entergy Texas
Entergy Gulf States Louisiana	Entergy Gulf States Louisiana, L.L.C., a Louisiana limited liability company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. and the successor company to Entergy Gulf States, Inc. for financial reporting purposes.  The term is also used to refer to the Louisiana jurisdictional business of Entergy Gulf States, Inc., as the context requires. Effective October 1, 2015, the business of Entergy Gulf States Louisiana was combined with Entergy Louisiana.
Entergy Louisiana	Entergy Louisiana, LLC, a Texas limited liability company formally created as part of the combination of Entergy Gulf States Louisiana and the company formerly known as Entergy Louisiana, LLC (Old Entergy Louisiana) into a single public utility company and the successor to Old Entergy Louisiana for financial reporting purposes.
Entergy Texas	Entergy Texas, Inc., a Texas corporation formally created as part of the jurisdictional separation of Entergy Gulf States, Inc.  The term is also used to refer to the Texas jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Wholesale Commodities	Entergy’s non-utility business segment primarily comprised of the ownership, operation, and decommissioning of nuclear power plants, the ownership of interests in non-nuclear power plants, and the sale of the electric power produced by its operating power plants to wholesale customers
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
Form 10-K	Annual Report on Form 10-K for the calendar year ended December 31, 2021 filed with the SEC by Entergy Corporation and its Registrant Subsidiaries
Grand Gulf	Unit No. 1 of Grand Gulf Nuclear Station (nuclear), 90% owned or leased by System Energy
GWh	Gigawatt-hour(s), which equals one million kilowatt-hours
HLBV	Hypothetical liquidation at book value

vi

DEFINITIONS (Continued)

Abbreviation or Acronym	Term
Independence	Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power, LLC
Indian Point 2	Unit 2 of Indian Point Energy Center (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2020 and was sold in May 2021
Indian Point 3	Unit 3 of Indian Point Energy Center (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2021 and was sold in May 2021
IRS	Internal Revenue Service
ISO	Independent System Operator
kW	Kilowatt, which equals one thousand watts
kWh	Kilowatt-hour(s)
LPSC	Louisiana Public Service Commission
MISO	Midcontinent Independent System Operator, Inc., a regional transmission organization
MMBtu	One million British Thermal Units
MPSC	Mississippi Public Service Commission
MW	Megawatt(s), which equals one thousand kilowatts
MWh	Megawatt-hour(s), which equals one thousand kilowatts
Nelson Unit 6	Unit No. 6 (coal) of the Nelson Steam Electric Generating Station, 70% of which is co-owned by Entergy Louisiana (57.5%) and Entergy Texas (42.5%) and 10.9% of which is owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Net debt to net capital ratio	Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents
NRC	Nuclear Regulatory Commission
Palisades	Palisades Nuclear Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Parent & Other	The portions of Entergy not included in the Utility or Entergy Wholesale Commodities segments, primarily consisting of the activities of the parent company, Entergy Corporation
PPA	Purchased power agreement or power purchase agreement
PUCT	Public Utility Commission of Texas
Registrant Subsidiaries	Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.
River Bend	River Bend Station (nuclear), owned by Entergy Louisiana
SEC	Securities and Exchange Commission
System Agreement	Agreement, effective January 1, 1983, as modified, among the Utility operating companies relating to the sharing of generating capacity and other power resources. The agreement terminated effective August 2016.
System Energy	System Energy Resources, Inc.
TWh	Terawatt-hour(s), which equals one billion kilowatt-hours

vii

DEFINITIONS (Concluded)

Abbreviation or Acronym	Term
Unit Power Sales Agreement	Agreement, dated as of June 10, 1982, as amended and approved by the FERC, among Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy, relating to the sale of capacity and energy from System Energy’s share of Grand Gulf
Utility	Entergy’s business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution
Utility operating companies	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas
Vermont Yankee	Vermont Yankee Nuclear Power Station (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in December 2014 and was disposed of in January 2019
Waterford 3	Unit No. 3 (nuclear) of the Waterford Steam Electric Station, owned by Entergy Louisiana
weather-adjusted usage	Electric usage excluding the effects of deviations from normal weather
White Bluff	White Bluff Steam Electric Generating Station, 57% owned by Entergy Arkansas

viii

ENTERGY CORPORATION AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Entergy operates primarily through two business segments: Utility and Entergy Wholesale Commodities.

•The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business.

•The Entergy Wholesale Commodities business segment includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of the operation and planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet.

See Note 7 to the financial statements herein for financial information regarding Entergy’s business segments.

1

Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Results of Operations

First Quarter 2022 Compared to First Quarter 2021

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the first quarter 2022 to the first quarter 2021 showing how much the line item increased or (decreased) in comparison to the prior period:

	Utility	Entergy Wholesale Commodities	Parent & Other (a)	Entergy
	(In Thousands)
2021 Net Income (Loss) Attributable to Entergy Corporation	$356,567	$37,577	($59,579)	$334,565
Operating revenues	131,540	(98,442)	(11)	33,087
Fuel, fuel-related expenses, and gas purchased for resale	160,924	4,836	11	165,771
Purchased power	(105,937)	(4,160)	(11)	(110,108)
Other regulatory charges (credits) - net	(60,704)	—	—	(60,704)
Other operation and maintenance	26,207	(57,721)	3,540	(27,974)
Asset write-offs, impairments, and related charges	—	(2,529)	—	(2,529)
Taxes other than income taxes	20,344	3,069	33	23,446
Depreciation and amortization	29,121	(4,219)	(449)	24,453
Other income (deductions)	(46,264)	(47,309)	(1,834)	(95,407)
Interest expense	15,442	(3,027)	9,238	21,653
Other expenses	1,698	(39,029)	—	(37,331)
Income taxes	15,625	(12,706)	(2,364)	555
Preferred dividend requirements of subsidiaries and noncontrolling interest	(1,339)	—	(48)	(1,387)
2022 Net Income (Loss) Attributable to Entergy Corporation	$340,462	$7,312	($71,374)	$276,400

(a)Parent & Other includes eliminations, which are primarily intersegment activity.

2

Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the first quarter 2022 to the first quarter 2021:

	Amount
	(In Millions)
2021 operating revenues	$2,597
Fuel, rider, and other revenues that do not significantly affect net income	30
Retail electric price	91
Return of unprotected excess accumulated deferred income taxes to customers	24
Volume/weather	(14)
2022 operating revenues	$2,728

The Utility operating companies’ results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to:

•increases in Entergy Arkansas’s formula rate plan rates effective May 2021 and January 2022;

•an increase in Entergy Louisiana’s formula rate plan revenues, including increases in the distribution and transmission recovery mechanisms, effective September 2021;

•increases in Entergy Mississippi’s formula rate plan rates effective April 2021 and July 2021;

•an increase in Entergy New Orleans’s formula rate plan rates effective November 2021; and

•increases in the transmission cost recovery factor rider effective March 2021 and March 2022, an increase in the distribution cost recovery factor rider effective January 2022, and an increase in the generation cost recovery rider effective January 2022, each at Entergy Texas.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the regulatory proceedings discussed above.

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at the Utility operating companies in response to the enactment of the Tax Cuts and Jobs Act. The return of unprotected excess accumulated deferred income taxes began in second quarter 2018. In the first quarter 2022, $17 million was returned to customers through reductions in operating revenues as compared to $41 million in the first quarter 2021. There is no effect on net income as the reductions in operating revenues were offset by reductions in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to the effect of less favorable weather on residential sales and a decrease in weather-adjusted residential usage, including the effect of the COVID-19 pandemic on first quarter 2021, partially offset by increases in industrial and commercial usage. The increase in industrial usage was due to an increase in demand from cogeneration customers, an increase in demand from existing customers, primarily in the chemicals and pulp and paper industries as a result of prior year temporary plant shutdowns and operational issues, an increase in demand from expansion projects, primarily in the chemicals, transportation, and petroleum

3

Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

refining industries, and an increase in demand from small industrial customers. The increase in commercial usage was primarily due to an increase in customers and the effect of the COVID-19 pandemic on businesses in first quarter 2021. The increased usage from these industrial and commercial customers has a relatively smaller effect on operating revenues because a larger portion of the revenues from those customers comes from fixed charges.

Total electric energy sales for Utility for the three months ended March 31, 2022 and 2021 are as follows:

	2022	2021	% Change
	(GWh)
Residential	8,454	8,663	(2)
Commercial	6,271	6,111	3
Industrial	12,496	11,738	6
Governmental	584	581	1
Total retail	27,805	27,093	3
Sales for resale	3,641	4,299	(15)
Total	31,446	31,392	—

See Note 13 to the financial statements herein for additional discussion of operating revenues.

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $248 million for the first quarter 2021 to $150 million for the first quarter 2022 primarily due to the shutdown of Indian Point 3 in April 2021.

Following are key performance measures for Entergy Wholesale Commodities for the first quarters 2022 and 2021:

	2022	2021
Owned capacity (MW) (a)	1,205	2,246
GWh billed	2,225	4,413
Entergy Wholesale Commodities Nuclear Fleet (b)
Capacity factor	100%	99%
GWh billed	1,766	3,988
Average energy price ($/MWh)	$59.21	$51.86
Average capacity price ($/kW-month)	$0.15	$0.23

(a)The reduction in owned capacity is due to the shutdown of the 1,041 MW Indian Point 3 plant in April 2021.

(b)The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the first quarters 2022 and 2021.

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Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $602 million for the first quarter 2021 to $628 million for the first quarter 2022 primarily due to:

•an increase of $6 million in customer service center support costs primarily due to higher contract costs;

•an increase of $5 million in nuclear generation expenses primarily due to a higher scope of work performed in 2022 as compared to prior year, partially offset by lower spending in 2022 on sanitation and social distancing protocols as a result of the COVID-19 pandemic;

•an increase of $4 million in transmission expenses, including higher vegetation maintenance costs;

•an increase of $3 million in distribution operations expenses primarily due to higher reliability costs and higher safety and training costs, partially offset by a decrease in meter reading expenses as a result of the deployment of advanced metering systems; and

•several individually insignificant items.

The increase was partially offset by higher nuclear insurance refunds of $8 million.

Taxes other than income taxes increased primarily due to increases in franchise taxes and increases in ad valorem taxes resulting from higher assessments.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other regulatory charges (credits) - net includes the reversal in 2021 of the remaining $39 million regulatory liability for Entergy Arkansas’s 2019 historical year netting adjustment as part of its 2020 formula rate plan proceeding. See Note 2 to the financial statements in the Form 10-K for discussion of the 2020 formula rate plan filing. In addition, Entergy records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and nuclear decommissioning trust earnings plus asset retirement obligation related costs collected in revenue.

Other income decreased primarily due to changes in decommissioning trust fund activity, including portfolio rebalancing of the decommissioning trust funds in the first quarter 2021.

Interest expense increased primarily due to:

•the issuance by Entergy Arkansas of $400 million of 3.35% Series mortgage bonds in March 2021;

•the issuances by Entergy Louisiana of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;

•the issuance by Entergy Louisiana of $1 billion of 0.95% Series mortgage bonds in October 2021;

•the issuance by Entergy Mississippi of $200 million of 3.50% Series mortgage bonds in March 2021;

•the $1.2 billion unsecured term loan proceeds received by Entergy Louisiana in January 2022;

•the issuance by Entergy Mississippi of $200 million of 2.55% Series mortgage bonds in November 2021; and

•the issuances by Entergy New Orleans of $70 million of 4.51% Series mortgage bonds and $90 million of 4.19% Series mortgage bonds, each in November 2021.

The increase was partially offset by the repayment by Entergy Arkansas of $350 million of 3.75% Series mortgage bonds in February 2021 and the repayment by Entergy Louisiana of $200 million of 4.8% Series mortgage bonds in May 2021.

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Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $99 million for the first quarter 2021 to $41 million for the first quarter 2022 primarily due to:

•a decrease of $44 million resulting from the absence of expenses from Indian Point 3, after it was shut down in April 2021; and

•a decrease of $10 million in severance and retention expenses. Severance and retention expenses were incurred in 2022 and 2021 due to management’s strategy to exit the Entergy Wholesale Commodities merchant power business.

See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses.

Other income decreased primarily due to the absence of earnings from the nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021 and lower gains on Palisades decommissioning trust fund investments, partially offset by lower non-service pension costs. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments. See Note 14 to the financial statements in the Form 10-K for further discussion of the sale of the Indian Point Energy Center. See Note 6 to the financial statements herein for a discussion of pension and other postretirement benefits costs.

Other expenses decreased primarily due to the absence of decommissioning expense from Indian Point 2 and Indian Point 3, after the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements in the Form 10-K for further discussion of the sale of the Indian Point Energy Center.

Income Taxes

The effective income tax rates were 19.2% for the first quarter 2022 and 16.3% for the first quarter 2021. The differences in the effective income tax rates for the first quarter 2022 and the first quarter 2021 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Entergy Wholesale Commodities Exit from the Merchant Power Business

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” in the Form 10-K for a discussion of management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant nuclear fleet.  Following are updates to that discussion.

In April 2022, Entergy and Nebraska Public Power District signed an agreement to mutually terminate the management support services contract, under which Entergy provides plant operation support services for the 800 MW Cooper Nuclear Station located near Brownville, Nebraska, effective July 31, 2022.

Planned Shutdown and Sale of Palisades

As discussed in the Form 10-K, in July 2018, Entergy entered into a purchase and sale agreement to sell 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site, for $1,000 (subject

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to adjustment for net liabilities and other amounts) to a Holtec subsidiary. The sale will include the transfer of the nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning.

Entergy intends to shut down Palisades permanently no later than May 31, 2022. Subject to the conditions discussed in the Form 10-K, the sale of Palisades is expected to close in mid-2022. As of March 31, 2022, Entergy’s adjusted net investment in Palisades was approximately ($100) million. The primary variables in the ultimate loss or gain that Entergy will incur on the transaction are the values of the nuclear decommissioning trust and the asset retirement obligations at closing, the financial results from plant operations until the closing, and the level of any unrealized deferred tax balances at closing.

Costs Associated with Exit of the Entergy Wholesale Commodities Business

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Liquidity and Capital Resources

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy’s capital structure, capital expenditure plans and other uses of capital, and sources of capital.  Following are updates to that discussion.

Capital Structure and Resources

Entergy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy as of March 31, 2022 is primarily due to the net issuance of debt in 2022.

	March 31, 2022		December 31, 2021
Debt to capital	70.5	%	69.5	%
Effect of excluding securitization bonds	(0.1	%)	(0.1	%)
Debt to capital, excluding securitization bonds (a)	70.4	%	69.4	%
Effect of subtracting cash	(0.5	%)	(0.3	%)
Net debt to net capital, excluding securitization bonds (a)	69.9	%	69.1	%

(a)Calculation excludes the New Orleans and Texas securitization bonds, which are non-recourse to Entergy New Orleans and Entergy Texas, respectively.

As of March 31, 2022, 21.5% of the debt outstanding is at the parent company, Entergy Corporation, 78% is at the Utility, and 0.5% is at Entergy Wholesale Commodities. Net debt consists of debt less cash and cash equivalents.  Debt consists of notes payable and commercial paper, finance lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt, common shareholders’ equity, and subsidiaries’ preferred stock without sinking fund.  Net capital consists of capital less cash and cash equivalents.  Entergy uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy’s financial condition because the securitization bonds are non-recourse to Entergy, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy’s financial condition because net debt indicates Entergy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the

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total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility. As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

A covenant in Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  The calculation of this debt ratio under Entergy Corporation’s credit facility is different than the calculation of the debt to capital ratio above.  Entergy is currently in compliance with the covenant and expects to remain in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.  See Note 4 to the financial statements herein for additional discussion of the Entergy Corporation credit facility and discussion of the Utility operating companies’ credit facilities.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Mississippi had $33 million in its storm reserve escrow account at March 31, 2022.

In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. A City Council decision is expected in third quarter 2022.

Equity Issuances and Equity Distribution Program

As discussed in the Form 10-K, in January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may also enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. Through March 31, 2022, Entergy has utilized the equity distribution program either to sell or to enter into forward sale agreements with respect to shares of common stock with an aggregate gross sales price of approximately $630 million, of which approximately $430 million of aggregate gross sales price is the subject of forward sale agreements that have not been settled and is subject to adjustment pursuant to the forward sale agreements. In addition to settlement of existing forward sale agreements, Entergy Corporation currently expects to issue approximately $570 million of equity through 2024. See Note 3 to the financial statements herein for discussion of the forward sale agreements and common stock issuances and sales under the equity distribution program.

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida (Entergy Louisiana)

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during

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the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC

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approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application, currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Hurricane Ida (Entergy New Orleans)

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K for a discussion of Hurricane Ida, which caused significant damage to Entergy’s service area, including Entergy’s electrical grid. Entergy New Orleans expects to initiate its storm cost recovery proceeding in late second quarter 2022.

Hurricane Laura, Hurricane Delta, and Winter Storm Uri (Entergy Texas)

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

Capital Expenditure Plans and Other Uses of Capital

See the table and discussion in the Form 10-K under “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital,” that sets forth the amounts of planned construction and other capital investments by operating segment for 2022 through 2024. Following are updates to that discussion. While Entergy is still assessing the effect on its planned solar projects, a recently commenced investigation by the U.S. Department of Commerce into potential circumvention of duties and tariffs may result in increased duties or tariffs on imported solar panels and has created supply chain disruptions which will affect the ultimate timing and could increase the cost of completion of these projects.

West Memphis Solar Facility

As discussed in the Form 10-K, in October 2021 the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. In April 2022, Entergy Arkansas filed its tax equity partnership status report and will file subsequent reports until a tax equity partnership is obtained or a tax equity partnership is no longer sought. Entergy Arkansas views the progress of the outreach to potential tax equity

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Management's Financial Discussion and Analysis

investors and the current status of the discussions as consistent with its expectations for the timeline for achieving a tax equity partnership. Closing had been expected to occur in 2023. The counter-party has notified Entergy Arkansas that it is seeking changes to certain terms of the build-own-transfer agreement, including both cost and schedule. Negotiations are ongoing, but at this time the project is not expected to achieve commercial operation in 2023.

Driver Solar Facility

In April 2022, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 250 MW Driver Solar Facility is in the public interest. The acquisition of Driver Solar will be contingent upon receiving all necessary regulatory and Board approvals. Entergy Arkansas requested a decision by the APSC by June 2022 and requested cost recovery through the formula rate plan rider. The APSC established a procedural schedule with a hearing scheduled in June 2022. The facility is expected to be in service by the end of 2024.

2021 Solar Certification and the Geaux Green Option

As discussed in the Form 10-K, in November 2021, Entergy Louisiana filed an application with the LPSC seeking certification of and approval for the addition of four new solar photovoltaic resources with a combined nameplate capacity of 475 megawatts (the 2021 Solar Portfolio) and the implementation of a new green tariff, the Geaux Green Option (Rider GGO). The LPSC has established a procedural schedule that is expected to result in an LPSC decision by the end of 2022. In March 2022 direct testimony from Walmart, the Louisiana Energy Users Group (LEUG) and the LPSC staff was filed. Each party recommended that the LPSC approve the resources proposed in Entergy Louisiana’s application, and the LPSC staff witness indicated that the process through which Entergy Louisiana solicited or obtained the proposals for the resources complies with applicable LPSC orders. LPSC staff and LEUG’s witnesses made recommendations to modify the proposed Rider GGO and Entergy Louisiana’s proposed rate relief. In April 2022, LPSC staff and LEUG filed cross-answering testimony concerning the other party’s proposed modifications to Rider GGO and the proposed rate recovery. Discovery concerning these parties’ testimonies is ongoing.

Sunflower Solar Facility

As discussed in the Form 10-K, in November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW solar photovoltaic facility that will be sited on approximately 1,000 acres in Sunflower County, Mississippi. The estimated total investment, including the base purchase price and other related costs, for Entergy Mississippi to acquire the Sunflower Solar Facility is approximately $153.2 million. Entergy Mississippi will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar Facility and its recovery through Entergy Mississippi’s interim capacity rate adjustment mechanism, subject to certain conditions including: (i) that Entergy Mississippi pursue a partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement, and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar Facility. The initial closing is targeted to occur in May 2022. In conjunction with closing, Entergy Mississippi is executing a partnership structure through which the partnership will acquire and own the Sunflower Solar Facility. Final payment of the purchase price will be made upon substantial completion of the facility, which is currently expected in third quarter 2022.

Orange County Advanced Power Station

As discussed in the Form 10-K, in September 2021, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to construct, own, and operate the Orange County Advanced Power Station, a new 1,215 MW combined-cycle combustion turbine facility to be

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located in Bridge City, Texas at an initially-estimated expected total cost of $1.2 billion inclusive of the estimated costs of the generation facilities, transmission upgrades, contingency, an allowance for funds used during construction, and necessary regulatory expenses, among others. The project includes combustion turbine technology with dual fuel capability, able to co-fire up to 30% hydrogen by volume upon commercial operation and upgradable to support 100% hydrogen operations in the future. In December 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2022 certain intervenors filed testimony opposing the hydrogen co-firing component of the proposed project and others filed opposing the project outright. Also in March 2022, PUCT staff filed testimony opposing the hydrogen co-firing component of the proposed project, but otherwise taking no specific position on the merits of the project. The PUCT staff also proposed that the PUCT establish a maximum amount that Entergy Texas may recover in rates attributable to the project. In April 2022, Entergy Texas filed rebuttal testimony addressing and rebutting these various arguments. Also in April 2022 the ALJs with the State Office of Administrative Hearings approved a continuance of the hearing on the merits from April 2022 to June 2022, providing Entergy Texas an opportunity to accelerate the determination and fixing of pricing for the Orange County Advanced Power Station prior to the hearing. A final order by the PUCT is expected in third or fourth quarter of 2022. Entergy Texas also is pursuing environmental permitting that is required prior to the commencement of construction. Subject to receipt of required regulatory approvals, permits, and other conditions, the facility is expected to be in service by May 2026.

Dividends

Declarations of dividends on Entergy’s common stock are made at the discretion of the Board.  Among other things, the Board evaluates the level of Entergy’s common stock dividends based upon earnings per share from the Utility operating segment and the Parent and Other portion of the business, financial strength, and future investment opportunities.  At its April 2022 meeting, the Board declared a dividend of $1.01 per share, which is the same quarterly dividend per share that Entergy has paid since the third quarter 2021.

Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Millions)
Cash and cash equivalents at beginning of period	$443	$1,759
Net cash provided by (used in):
Operating activities	538	(49)
Investing activities	(1,551)	(1,513)
Financing activities	1,272	1,546
Net increase (decrease) in cash and cash equivalents	259	(16)
Cash and cash equivalents at end of period	$702	$1,743

Operating Activities

Entergy’s operating activities provided $538 million of cash for the three months ended March 31, 2022 compared to using $49 million of cash for the three months ended March 31, 2021 primarily due to the following activity:

•higher collections from Utility customers;

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•decreased fuel costs, including costs related to Winter Storm Uri in 2021. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•a decrease of $84 million in pension contributions in 2022 as compared to the same period in 2021. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding; and

•an increase of $43 million in proceeds received from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.

The above activity was partially offset by:

•an increase of approximately $128 million in storm spending primarily due to Hurricane Ida. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K for discussion of storm restoration efforts; and

•lower Entergy Wholesale Commodities revenues in 2022.

Investing Activities

Net cash flow used in investing activities increased $38 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•an increase of $50 million in nuclear construction expenditures primarily due to increased spending on various nuclear projects in 2022;

•a decrease of $44 million in net receipts from storm reserve escrow accounts;

•an increase of $35 million in nuclear fuel purchases due to variations from year to year in the timing and pricing of fuel reload requirements, materials and services deliveries, and the timing of cash payments during the nuclear fuel cycle; and

•an increase of $27 million in information technology capital expenditures primarily due to increased spending on various technology projects in 2022.

The increase was partially offset by:

•a decrease of $92 million in transmission construction expenditures primarily due to lower capital expenditures for storm restoration in 2022; and

•a decrease of $25 million in non-nuclear generation construction expenditures primarily due to higher spending in 2021 on the Montgomery County Power Station project.

Financing Activities

Net cash flow provided by financing activities decreased $274 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to long-term debt activity providing approximately $1,329 million of cash in 2022 compared to providing approximately $2,330 million of cash in 2021. The decrease was partially offset by an increase of $741 million in net issuances of commercial paper in 2022 compared to 2021. For details of Entergy’s commercial paper program and long-term debt, see Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K.

Rate, Cost-recovery, and Other Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Rate, Cost-recovery, and Other Regulation” in the Form 10-K for discussions of rate regulation, federal regulation, and related regulatory proceedings.

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State and Local Rate Regulation and Fuel-Cost Recovery

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding these proceedings.

Federal Regulation

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding federal regulatory proceedings.

Market and Credit Risk Sensitive Instruments

Entergy Wholesale Commodities Portfolio

Some of the agreements to sell the power produced by Entergy Wholesale Commodities’ power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations under the agreements. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  Cash and letters of credit are also acceptable forms of credit support. At March 31, 2022, based on power prices at that time, Entergy had liquidity exposure of $26 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $8 million of posted cash collateral. In the event of a decrease in Entergy Corporation’s credit rating to below investment grade, based on power prices as of March 31, 2022, Entergy would have been required to provide approximately $30 million of additional cash or letters of credit under some of the agreements. As of March 31, 2022, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by an insignificant amount for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.

As of March 31, 2022, substantially all of the credit exposure associated with the planned energy output under contract for the Palisades plant through 2022 is with counterparties or their guarantors that have public investment grade credit ratings.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See Note 1 to the financial statements in the Form 10-K for discussion of new accounting pronouncements.

14

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands, Except Share Data)
OPERATING REVENUES
Electric	$2,655,776	$2,538,420
Natural gas	72,361	58,168
Competitive businesses	149,788	248,250
TOTAL	2,877,925	2,844,838
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	666,938	501,167
Purchased power	269,626	379,734
Nuclear refueling outage expenses	43,002	43,739
Other operation and maintenance	678,812	706,786
Asset write-offs, impairments, and related charges	744	3,273
Decommissioning	62,048	98,642
Taxes other than income taxes	180,148	156,702
Depreciation and amortization	438,972	414,519
Other regulatory charges (credits) - net	(28,425)	32,279
TOTAL	2,311,865	2,336,841
OPERATING INCOME	566,060	507,997
OTHER INCOME
Allowance for equity funds used during construction	15,871	14,577
Interest and investment income (loss)	(21,918)	143,315
Miscellaneous - net	7,603	(60,929)
TOTAL	1,556	96,963
INTEREST EXPENSE
Interest expense	227,622	205,886
Allowance for borrowed funds used during construction	(6,096)	(6,013)
TOTAL	221,526	199,873
INCOME BEFORE INCOME TAXES	346,090	405,087
Income taxes	66,497	65,942
CONSOLIDATED NET INCOME	279,593	339,145
Preferred dividend requirements of subsidiaries and noncontrolling interest	3,193	4,580
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$276,400	$334,565
Earnings per average common share:
Basic	$1.36	$1.67
Diluted	$1.36	$1.66
Basic average number of common shares outstanding	202,943,628	200,525,549
Diluted average number of common shares outstanding	203,888,483	201,059,665
See Notes to Financial Statements.

15

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16

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
Net Income	$279,593	$339,145
Other comprehensive loss
Cash flow hedges net unrealized gain (loss) (net of tax benefit of $— and $7,869)	24	(29,580)
Pension and other postretirement liabilities (net of tax expense of $2,542, and $6,314)	8,328	22,967
Net unrealized investment loss (net of tax benefit of $7,221 and $25,581)	(12,402)	(44,687)
Other comprehensive loss	(4,050)	(51,300)
Comprehensive Income	275,543	287,845
Preferred dividend requirements of subsidiaries and noncontrolling interest	3,193	4,580
Comprehensive Income Attributable to Entergy Corporation	$272,350	$283,265
See Notes to Financial Statements.

17

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING ACTIVITIES
Consolidated net income	$279,593	$339,145
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	561,731	580,571
Deferred income taxes, investment tax credits, and non-current taxes accrued	70,780	240,431
Asset write-offs, impairments, and related charges	744	3,278
Changes in working capital:
Receivables	122,987	(52,690)
Fuel inventory	14,795	26,878
Accounts payable	(283,175)	(175,651)
Taxes accrued	(79,941)	(231,182)
Interest accrued	32,862	(3,778)
Deferred fuel costs	(58,932)	(353,099)
Other working capital accounts	(95,033)	(43,582)
Changes in provisions for estimated losses	8,206	(60,923)
Changes in other regulatory assets	(1,424,270)	89,910
Changes in other regulatory liabilities	(250,358)	(14,464)
Storm restoration costs approved for securitization recognized as regulatory asset	1,491,942	—
Changes in pension and other postretirement liabilities	(101,641)	(166,733)
Other	247,676	(227,676)
Net cash flow provided by (used in) operating activities	537,966	(49,565)
INVESTING ACTIVITIES
Construction/capital expenditures	(1,501,578)	(1,552,103)
Allowance for equity funds used during construction	15,871	14,577
Nuclear fuel purchases	(83,326)	(47,916)
Litigation proceeds from settlement agreement	9,829	—
Changes in securitization account	13,532	(1,304)
Payments to storm reserve escrow account	—	(10)
Receipts from storm reserve escrow account	—	44,205
Decrease (increase) in other investments	(11,862)	12,521
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	32,367	15,735
Proceeds from nuclear decommissioning trust fund sales	479,937	3,225,510
Investment in nuclear decommissioning trust funds	(505,989)	(3,224,487)
Net cash flow used in investing activities	(1,551,219)	(1,513,272)
See Notes to Financial Statements.

18

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt	2,553,369	3,676,242
Treasury stock	9,629	979
Retirement of long-term debt	(1,224,091)	(1,346,172)
Changes in credit borrowings and commercial paper - net	141,634	(599,860)
Other	1,382	10,380
Dividends paid:
Common stock	(205,058)	(190,595)
Preferred stock	(4,580)	(4,580)
Net cash flow provided by financing activities	1,272,285	1,546,394
Net increase (decrease) in cash and cash equivalents	259,032	(16,443)
Cash and cash equivalents at beginning of period	442,559	1,759,099
Cash and cash equivalents at end of period	$701,591	$1,742,656
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$186,269	$202,451
Income taxes	($11,505)	$9,015
See Notes to Financial Statements.

19

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$76,146	$44,944
Temporary cash investments	625,445	397,615
Total cash and cash equivalents	701,591	442,559
Accounts receivable:
Customer	668,620	786,866
Allowance for doubtful accounts	(31,486)	(68,608)
Other	171,858	231,843
Accrued unbilled revenues	406,010	420,255
Total accounts receivable	1,215,002	1,370,356
Deferred fuel costs	375,670	324,394
Fuel inventory - at average cost	139,780	154,575
Materials and supplies - at average cost	1,066,535	1,041,515
Deferred nuclear refueling outage costs	125,192	133,422
Prepayments and other	215,231	156,774
TOTAL	3,839,001	3,623,595
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	5,210,130	5,514,016
Non-utility property - at cost (less accumulated depreciation)	357,092	357,576
Other	159,728	159,455
TOTAL	5,726,950	6,031,047
PROPERTY, PLANT, AND EQUIPMENT
Electric	63,405,911	64,263,250
Natural gas	666,646	658,989
Construction work in progress	1,556,651	1,511,966
Nuclear fuel	547,706	577,006
TOTAL PROPERTY, PLANT, AND EQUIPMENT	66,176,914	67,011,211
Less - accumulated depreciation and amortization	24,982,767	24,767,051
PROPERTY, PLANT, AND EQUIPMENT - NET	41,194,147	42,244,160
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $34,145 as of March 31, 2022 and $49,579 as of December 31, 2021)	8,037,526	6,613,256
Deferred fuel costs	241,002	240,953
Goodwill	377,172	377,172
Accumulated deferred income taxes	58,388	54,186
Other	359,340	269,873
TOTAL	9,073,428	7,555,440
TOTAL ASSETS	$59,833,526	$59,454,242
See Notes to Financial Statements.

20

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$1,039,335	$1,039,329
Notes payable and commercial paper	1,342,811	1,201,177
Accounts payable	1,741,052	2,610,132
Customer deposits	402,600	395,184
Taxes accrued	339,887	419,828
Interest accrued	224,013	191,151
Deferred fuel costs	—	7,607
Pension and other postretirement liabilities	60,249	68,336
Current portion of unprotected excess accumulated deferred income taxes	35,241	53,385
Other	177,997	204,613
TOTAL	5,363,185	6,190,742
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	4,796,208	4,706,797
Accumulated deferred investment tax credits	209,921	211,975
Regulatory liability for income taxes-net	1,233,417	1,255,692
Other regulatory liabilities	2,433,906	2,643,845
Decommissioning and asset retirement cost liabilities	4,816,524	4,757,084
Accumulated provisions	165,328	157,122
Pension and other postretirement liabilities	1,855,771	1,949,325
Long-term debt (includes securitization bonds of $54,674 as of March 31, 2022 and $83,639 as of December 31, 2021)	26,176,449	24,841,572
Other	786,581	815,284
TOTAL	42,474,105	41,338,696
Commitments and Contingencies
Subsidiaries' preferred stock without sinking fund	219,410	219,410
EQUITY
Preferred stock, no par value, authorized 1,000,000 shares in 2022 and 2021; issued shares in 2022 and 2021 - none	—	—
Common stock, $.01 par value, authorized 499,000,000 shares in 2022 and 2021; issued 271,965,510 shares in 2022 and 2021	2,720	2,720
Paid-in capital	6,735,154	6,766,239
Retained earnings	10,311,894	10,240,552
Accumulated other comprehensive loss	(336,578)	(332,528)
Less - treasury stock, at cost (68,808,788 shares in 2022 and 69,312,326 shares in 2021)	5,003,087	5,039,699
Total common shareholders' equity	11,710,103	11,637,284
Subsidiaries' preferred stock without sinking fund and noncontrolling interest	66,723	68,110
TOTAL	11,776,826	11,705,394
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$59,833,526	$59,454,242
See Notes to Financial Statements.

21

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
		Common Shareholders’ Equity
	Subsidiaries’ Preferred Stock and Noncontrolling Interest	Common Stock	Treasury Stock	Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Loss	Total
	(In Thousands)

Balance at December 31, 2020	$35,000	$2,700	($5,074,456)	$6,549,923	$9,897,182	($449,207)	$10,961,142
Consolidated net income (a)	4,580	—	—	—	334,565	—	339,145
Other comprehensive loss	—	—	—	—	—	(51,300)	(51,300)
Common stock issuances related to stock plans	—	—	28,235	(29,871)	—	—	(1,636)
Common stock dividends declared	—	—	—	—	(190,595)	—	(190,595)
Preferred dividend requirements of subsidiaries (a)	(4,580)	—	—	—	—	—	(4,580)
Balance at March 31, 2021	$35,000	$2,700	($5,046,221)	$6,520,052	$10,041,152	($500,507)	$11,052,176

Balance at December 31, 2021	$68,110	$2,720	($5,039,699)	$6,766,239	$10,240,552	($332,528)	$11,705,394
Consolidated net income (a)	3,193	—	—	—	276,400	—	279,593
Other comprehensive loss	—	—	—	—	—	(4,050)	(4,050)
Common stock issuances related to stock plans	—	—	36,612	(31,085)	—	—	5,527
Common stock dividends declared	—	—	—	—	(205,058)	—	(205,058)
Preferred dividend requirements of subsidiaries (a)	(4,580)	—	—	—	—	—	(4,580)
Balance at March 31, 2022	$66,723	$2,720	($5,003,087)	$6,735,154	$10,311,894	($336,578)	$11,776,826
See Notes to Financial Statements.
(a) Consolidated net income and preferred dividend requirements of subsidiaries for first quarter 2022 and first quarter 2021 each includes $4 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.

22

ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

23

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

24

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

25

Entergy Corporation and Subsidiaries

Notes to Financial Statements

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

26

Entergy Corporation and Subsidiaries

Notes to Financial Statements

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

27

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Notes to Financial Statements

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

28

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Notes to Financial Statements

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

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Notes to Financial Statements

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

NOTE 3.  EQUITY (Entergy Corporation and Entergy Louisiana)

Common Stock

Earnings per Share

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:

	For the Three Months Ended March 31,
	2022			2021
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$276.4	202.9	$1.36	$334.6	200.5	$1.67
Average dilutive effect of:
Stock options		0.5	—		0.4	(0.01)
Other equity plans		0.4	—		0.2	—
Equity forwards		0.1	—		—	—
Diluted earnings per share	$276.4	203.9	$1.36	$334.6	201.1	$1.66

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.9 million for the three months ended March 31, 2022 and approximately 1 million for the three months ended March 31, 2021.

Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K.

Dividends declared per common share were $1.01 for the three months ended March 31, 2022 and $0.95 for the three months ended March 31, 2021.

Equity Distribution Program

In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion, of which an aggregate gross sales price of approximately $633 million has been sold through March 31, 2022. See Note 7 to the financial statements in the Form 10-K for discussion of the common stock issued and unsettled forward sale agreements entered into during 2021. For the three months ended March 31, 2022, there were no shares of common stock issued under the at the market equity distribution program.

In March 2022, Entergy entered into a forward sale agreement for 1,538,010 shares of common stock. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreement occur. The forward sale agreement requires Entergy to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 1,538,010 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $108.14 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million. In connection with the sale of these shares, Entergy paid the forward sellers fees of approximately $1.7 million, which have not been deducted from the gross sales price. Entergy did not receive any proceeds from such sales of borrowed shares.

Until settlement of the forward sale agreement, earnings per share dilution resulting from the agreement, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. For the three months ended March 31, 2022, 1,775,251 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.

Treasury Stock

During the three months ended March 31, 2022, Entergy Corporation issued 503,538 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the three months ended March 31, 2022.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Retained Earnings

On April 11, 2022, Entergy Corporation’s Board of Directors declared a common stock dividend of $1.01 per share, payable on June 1, 2022 to holders of record as of May 5, 2022.

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2022 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2022	($1,035)	($338,647)	$7,154	($332,528)
Other comprehensive income (loss) before reclassifications	(14)	—	(15,875)	(15,889)
Amounts reclassified from accumulated other comprehensive income (loss)	38	8,328	3,473	11,839
Net other comprehensive income (loss) for the period	24	8,328	(12,402)	(4,050)
Ending balance, March 31, 2022	($1,011)	($330,319)	($5,248)	($336,578)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2021 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2021	$28,719	($534,576)	$56,650	($449,207)
Other comprehensive income (loss) before reclassifications	1,482	—	(45,301)	(43,819)
Amounts reclassified from accumulated other comprehensive income (loss)	(31,062)	22,967	614	(7,481)
Net other comprehensive income (loss) for the period	(29,580)	22,967	(44,687)	(51,300)
Ending balance, March 31, 2021	($861)	($511,609)	$11,963	($500,507)

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2022 and 2021:

	Pension and Other Postretirement Liabilities
	2022	2021
	(In Thousands)
Beginning balance, January 1,	$8,278	$4,327
Amounts reclassified from accumulated other comprehensive income (loss)	(613)	(407)
Net other comprehensive income (loss) for the period	(613)	(407)
Ending balance, March 31,	$7,665	$3,920

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$—	$39,367	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	(48)	39,319
Income taxes	10	(8,257)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	($38)	$31,062
Pension and other postretirement liabilities
Amortization of prior-service credit	$3,837	$5,248	(a)
Amortization of loss	(13,925)	(34,529)	(a)
Settlement loss	(782)	—	(a)
Total amortization	(10,870)	(29,281)
Income taxes	2,542	6,314	Income taxes
Total amortization (net of tax)	($8,328)	($22,967)
Net unrealized investment gain (loss)
Realized gain (loss)	($5,495)	($972)	Interest and investment income
Income taxes	2,022	358	Income taxes
Total realized investment gain (loss) (net of tax)	($3,473)	($614)
Total reclassifications for the period (net of tax)	($11,839)	$7,481

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,158	$1,230	(a)
Amortization of loss	(319)	(679)	(a)
Total amortization	839	551
Income taxes	(226)	(144)	Income taxes
Total amortization (net of tax)	613	407
Total reclassifications for the period (net of tax)	$613	$407

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

40

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

NOTE 5.  STOCK-BASED COMPENSATION (Entergy Corporation)

Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K.  Awards under Entergy’s plans generally vest over three years.

Stock Options

Entergy granted options on 444,028 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2022 with a fair value of $16.25 per option.  As of March 31, 2022, there were options on 3,128,304 shares of common stock outstanding with a weighted-average exercise price of $94.35.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of March 31, 2022.  The aggregate intrinsic value of the stock options outstanding as of March 31, 2022 was $77.6 million.

The following table includes financial information for outstanding stock options for the three months ended March 31, 2022 and 2021:

	2022	2021
	(In Millions)
Compensation expense included in Entergy’s consolidated net income	$1.1	$1.0
Tax benefit recognized in Entergy’s consolidated net income	$0.3	$0.3
Compensation cost capitalized as part of fixed assets and materials and supplies	$0.4	$0.4

Other Equity Awards

In January 2022 the Board approved and Entergy granted 328,849 restricted stock awards and 170,966 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on January 27, 2022 and were valued at $109.59 per share, which was the closing price of Entergy’s common stock on that date.  Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period. One-third of the restricted stock awards and accrued dividends will vest upon each anniversary of the grant date.  

In addition, long-term incentive awards were also granted in the form of performance units that represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. To emphasize the importance of strong cash generation for the long-term health of its business, a credit measure – adjusted funds from operations/debt ratio – was selected for the 2022-2024 performance period. Performance will be measured based eighty percent on relative total shareholder return and twenty percent on the credit measure.  The performance units were granted on January 27, 2022 and eighty percent were valued at $138.99 per share based on various factors, primarily market conditions; and twenty percent were valued at $109.59 per share, the closing price of Entergy’s common stock on that date.  Performance units have the same dividend rights as shares of Entergy common stock and are considered issued and outstanding shares of Entergy upon vesting. Performance units are expensed ratably over the three-year vesting period and compensation cost for the portion of the award based on cumulative adjusted earnings per share will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program.

The following table includes financial information for other outstanding equity awards for the three months ended March 31, 2022 and 2021:

	2022	2021
	(In Millions)
Compensation expense included in Entergy’s consolidated net income	$11.4	$10.8
Tax benefit recognized in Entergy’s consolidated net income	$2.9	$2.7
Compensation cost capitalized as part of fixed assets and materials and supplies	$4.4	$4.0

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

NOTE 6.  RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

45

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

NOTE 7.  BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

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Notes to Financial Statements

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

NOTE 8.  RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

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rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

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Notes to Financial Statements

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

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Notes to Financial Statements

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

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comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

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Notes to Financial Statements

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

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estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

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Notes to Financial Statements

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

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Notes to Financial Statements

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

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of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

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Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

60

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Notes to Financial Statements

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

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2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

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Notes to Financial Statements

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

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Notes to Financial Statements

NOTE 9.  DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($175) million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$2,070	$15	$99
2021
Debt Securities	$2,177	$65	$12

The unrealized gains/(losses) above are reported before deferred taxes of ($5) million as of March 31, 2022 and $2 million as of December 31, 2021 for debt securities. The amortized cost of available-for-sale debt securities was $2,153 million as of March 31, 2022 and $2,125 million as of December 31, 2021.  As of March 31, 2022, available-for-sale debt securities had an average coupon rate of approximately 2.77%, an average duration of approximately 6.63 years, and an average maturity of approximately 10.40 years.

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Notes to Financial Statements

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,419	$83	$770	$8
More than 12 months	119	16	99	4
Total	$1,538	$99	$869	$12

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$76	$—
1 year - 5 years	692	473
5 years - 10 years	600	655
10 years - 15 years	150	389
15 years - 20 years	158	130
20 years+	394	530
Total	$2,070	$2,177

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $303 million and $524 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $1 million and $11 million, respectively, and gross losses of $12 million and $11 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of March 31, 2022 and December 31, 2021 was $539 million and $576 million, respectively, for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

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Notes to Financial Statements

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$509.3	$1.4	$28.3
2021
Debt Securities	$526.3	$11.4	$4.7

The amortized cost of available-for-sale debt securities was $536.2 million as of March 31, 2022 and $519.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.49 years, and an average maturity of approximately 7.74 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($50.5) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$332.9	$21.3	$183.8	$2.9
More than 12 months	55.8	7.0	39.5	1.8
Total	$388.7	$28.3	$223.3	$4.7

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Notes to Financial Statements

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$33.8	$—
1 year - 5 years	153.6	91.7
5 years - 10 years	220.8	217.4
10 years - 15 years	47.9	146.0
15 years - 20 years	27.3	35.7
20 years+	25.9	35.5
Total	$509.3	$526.3

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $7.2 million and $13.8 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.03 million and $0.8 million, respectively, and gross losses of $0.2 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$747.5	$9.7	$30.2
2021
Debt Securities	$794.2	$31.3	$3.3

The amortized cost of available-for-sale debt securities was $767.9 million as of March 31, 2022 and $766.3 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 3.37%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.16 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($70) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

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Notes to Financial Statements

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$427.4	$25.1	$206.9	$1.4
More than 12 months	41.2	5.1	42.9	1.9
Total	$468.6	$30.2	$249.8	$3.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$29.2	$—
1 year - 5 years	193.9	157.8
5 years - 10 years	170.0	173.0
10 years - 15 years	68.5	123.0
15 years - 20 years	82.9	80.2
20 years+	203.0	260.2
Total	$747.5	$794.2

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $120.5 million and $108.4 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.9 million and $3.3 million, respectively, and gross losses of $5.5 million and $3.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$499.6	$1.9	$27.6
2021
Debt Securities	$524.5	$11.8	$2.9

The amortized cost of available-for-sale debt securities was $525.3 million as of March 31, 2022 and $515.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

average coupon rate of approximately 2.38%, an average duration of approximately 6.97 years, and an average maturity of approximately 9.87 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($47.7) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

		March 31, 2022		December 31, 2021
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$418.4	$25.5	$276.6	$2.3
More than 12 months		13.3	2.1	11.3	0.6
Total		$431.7	$27.6	$287.9	$2.9

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$6.9	$—
1 year - 5 years	217.3	156.8
5 years - 10 years	136.1	161.8
10 years - 15 years	9.5	58.6
15 years - 20 years	31.1	1.9
20 years+	98.7	145.4
Total	$499.6	$524.5

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $36.2 million and $74.1 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.1 million and $1.2 million, respectively, and gross losses of $0.7 million and $1.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

Entergy estimates the expected credit losses for its available-for-sale securities based on the current credit rating and remaining life of the securities.  To the extent an individual security is determined to be uncollectible, it is written off against this allowance.  Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities.  As of March 31, 2022 and December 31, 2021, Entergy’s allowance for expected credit losses related to available-for-sale securities were $3.2 million and $0.4 million, respectively. Entergy recorded $1.5 million in impairments of available-for-sale debt securities for the three months ended March 31, 2022.

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Notes to Financial Statements

Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021.

NOTE 10.  INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

NOTE 11.  PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

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Notes to Financial Statements

NOTE 12.  VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

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Notes to Financial Statements

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

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Notes to Financial Statements

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

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Notes to Financial Statements

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

________________

In the opinion of the management of Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, the accompanying unaudited financial statements contain all adjustments (consisting primarily of normal recurring accruals and reclassification of previously reported amounts to conform to current classifications) necessary for a fair statement of the results for the interim periods presented.  Entergy’s business is subject to seasonal fluctuations, however, with peak periods

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Notes to Financial Statements

occurring typically during the first and third quarters.  The results for the interim periods presented should not be used as a basis for estimating results of operations for a full year.

Part I, Item 3. Quantitative and Qualitative Disclosures About Market Risk

See “Market and Credit Risk Sensitive Instruments” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis.

Part I, Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of March 31, 2022, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy (individually “Registrant” and collectively the “Registrants”) management, including their respective Principal Executive Officers (PEO) and Principal Financial Officers (PFO). The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures. Based on the evaluations, each PEO and PFO has concluded that, as to the Registrant or Registrants for which they serve as PEO or PFO, the Registrant’s or Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in Securities and Exchange Commission rules and forms; and that the Registrant’s or Registrants’ disclosure controls and procedures are also effective in reasonably assuring that such information is accumulated and communicated to the Registrant’s or Registrants’ management, including their respective PEOs and PFOs, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Controls over Financial Reporting

Under the supervision and with the participation of each Registrants’ management, including its respective PEO and PFO, each Registrant evaluated changes in internal control over financial reporting that occurred during the quarter ended March 31, 2022 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Net income decreased $27.5 million primarily due to the reversal in 2021 of the remaining regulatory liability for the formula rate plan 2019 historical year netting adjustment and higher depreciation and amortization expenses, partially offset by higher retail electric price.

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2022 to the first quarter 2021:

	Amount
	(In Millions)
2021 operating revenues	$583.4
Fuel, rider, and other revenues that do not significantly affect net income	(55.4)
Volume/weather	(3.1)
Return of unprotected excess accumulated deferred income taxes to customers	8.0
Retail electric price	26.1
2022 operating revenues	$559.0

Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to the effect of less favorable weather on residential sales, partially offset by increases in commercial and industrial usage. The increase in commercial usage was primarily due to an increase in customers and the effect of the COVID-19 pandemic on businesses in first quarter 2021. The increase in industrial usage was primarily due to an increase in demand from existing customers, primarily in the wood products and petroleum refining industries.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a tax adjustment rider beginning in April 2018. In the first quarter 2021, $8 million was returned to customers. There is no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The retail electric price variance is primarily due to increases in formula rate plan rates effective May 2021 and January 2022. See Note 2 to the financial statements in the Form 10-K for further discussion of the 2020 formula rate plan filing and the 2021 formula rate plan filing.

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Management's Financial Discussion and Analysis

Total electric energy sales for Entergy Arkansas for the three months ended March 31, 2022 and 2021 are as follows:

	2022	2021	% Change
	(GWh)
Residential	2,092	2,185	(4)
Commercial	1,307	1,262	4
Industrial	1,972	1,947	1
Governmental	55	54	2
Total retail	5,426	5,448	—
Sales for resale:
Associated companies	486	597	(19)
Non-associated companies	1,391	2,030	(31)
Total	7,303	8,075	(10)

See Note 13 to the financial statements herein for additional discussion of Entergy Arkansas’s operating revenues.

Other Income Statement Variances

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Searcy Solar facility, which was placed in service in December 2021.

Other regulatory charges (credits) - net includes the reversal in 2021 of the remaining $38.8 million regulatory liability for the 2019 historical year netting adjustment as part of its 2020 formula rate plan proceeding. See Note 2 to the financial statements in the Form 10-K for discussion of the 2020 formula rate plan filing. In addition, Entergy Arkansas records a regulatory charge or credit for the difference between asset retirement obligation-related expenses and nuclear decommissioning trust earnings plus asset retirement obligation related costs collected in revenue.

Other income decreased primarily due to changes in decommissioning trust fund activity, including portfolio rebalancing of the ANO 1 and ANO 2 decommissioning trust funds in the first quarter 2021.

Noncontrolling interest reflects the earnings or losses attributable to the noncontrolling interest partner of the tax equity partnership for the Searcy Solar facility under HLBV accounting. Entergy Arkansas has recorded a regulatory charge of $1.5 million in first quarter 2022 to defer the difference between the losses allocated to the tax equity partner under the HLBV method of accounting and the earnings/loss that would have been allocated to the tax equity partner under its respective ownership percentage in the partnership. See Note 1 to the financial statements in the Form 10-K for discussion of the HLBV method of accounting.

Income Taxes

The effective income tax rate was 22.6% for the first quarter 2022. The difference in the effective income tax rate for the first quarter 2022 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

The effective income tax rate was 17.3% for the first quarter 2021. The difference in the effective income tax rate for the first quarter 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the

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Management's Financial Discussion and Analysis

financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Cash and cash equivalents at beginning of period	$12,915	$192,128
Net cash provided by (used in):
Operating activities	247,426	91,573
Investing activities	(214,477)	(162,611)
Financing activities	64,167	2,690
Net increase (decrease) in cash and cash equivalents	97,116	(68,348)
Cash and cash equivalents at end of period	$110,031	$123,780

Operating Activities

Net cash flow provided by operating activities increased $155.9 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•higher collections from customers;

•decreased fuel costs, including costs related to Winter Storm Uri in 2021. See Note 2 to the financial statements in the 10-K for a discussion of fuel and purchased power cost recovery;

•a decrease of $9.7 million in storm spending in 2022 primarily due to increased spending on Winter Storm Uri restoration efforts in 2021; and

•a decrease of $6.3 million in pension contributions in 2022. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

Investing Activities

Net cash flow used in investing activities increased $51.9 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•money pool activity;

•an increase of $14 million in distribution construction expenditures primarily due to higher capital expenditures for storm restoration, partially offset by lower spending on advanced metering infrastructure in 2022; and

•an increase of $10.2 million in nuclear construction expenditures primarily due to increased spending on various nuclear projects in 2022.

The increase was partially offset by a decrease of $11.5 million as a result of fluctuations in nuclear fuel activity primarily due to variations from year to year in the timing and pricing of fuel reload requirements, materials and services deliveries, and the timing of cash payments during the nuclear fuel cycle.

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Entergy Arkansas, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Increases in Entergy Arkansas’s receivable from the money pool are a use of cash flow, and Entergy Arkansas’s receivable from the money pool increased by $60 million for the three months ended March 31, 2022 compared to increasing by $12.5 million for the three months ended March 31, 2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities increased $61.5 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•the repayment, at maturity, of $350 million of 3.75% Series mortgage bonds due February 2021;

•the issuance of $200 million of 4.20% Series mortgage bonds in March 2022; and

•the repayment, at maturity, of $45 million of 2.375% Series governmental bonds due January 2021.

The increase was partially offset by the issuance of $400 million of 3.35% Series mortgage bonds in March 2021 and money pool activity.

Decreases in Entergy Arkansas’s payable to the money pool are a use of cash flow, and Entergy Arkansas’s payable to the money pool decreased by $139.9 million for the three months ended March 31, 2022.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Arkansas’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to the issuance of long-term debt in 2022.

	March 31, 2022		December 31, 2021
Debt to capital	53.4	%	52.6	%
Effect of subtracting cash	(0.6	%)	—	%
Net debt to net capital	52.8	%	52.6	%

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, finance lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Arkansas uses the debt to capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition.  Entergy Arkansas also uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition because net debt indicates Entergy Arkansas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Arkansas’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

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Management's Financial Discussion and Analysis

Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:

March 31, 2022	December 31, 2021	March 31, 2021	December 31, 2020
(In Thousands)
$59,981	($139,904)	$15,610	$3,110

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Arkansas has a credit facility in the amount of $150 million scheduled to expire in June 2026. Entergy Arkansas also has a $25 million credit facility scheduled to expire in July 2022. The $150 million credit facility includes fronting commitments for the issuance of letters of credit against $5 million of the borrowing capacity of the facility. As of March 31, 2022, there were no cash borrowings and no letters of credit outstanding under the credit facilities. In addition, Entergy Arkansas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of March 31, 2022, $7.5 million in letters of credit were outstanding under Entergy Arkansas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for further discussion of the credit facilities.

The Entergy Arkansas nuclear fuel company variable interest entity has a credit facility in the amount of $80 million scheduled to expire in June 2024.  As of March 31, 2022, there were no loans outstanding under the credit facility for the Entergy Arkansas nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for further discussion of the nuclear fuel company variable interest entity credit facility.

See the table and discussion in the Form 10-K under “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Uses of Capital,” that sets forth the amounts of planned construction and other capital investments for 2022 through 2024. While Entergy Arkansas is still assessing the effect on its planned solar projects, a recently commenced investigation by the U.S. Department of Commerce into potential circumvention of duties and tariffs may result in increased duties or tariffs on imported solar panels and has created supply chain disruptions which will affect the ultimate timing and could increase the cost of completion of these projects.

West Memphis Solar Facility

As discussed in the Form 10-K, in October 2021 the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. In April 2022, Entergy Arkansas filed its tax equity partnership status report and will file subsequent reports until a tax equity partnership is obtained or a tax equity partnership is no longer sought. Entergy Arkansas views the progress of the outreach to potential tax equity investors and the current status of the discussions as consistent with its expectations for the timeline for achieving a tax equity partnership. Closing had been expected to occur in 2023. The counter-party has notified Entergy Arkansas that it is seeking changes to certain terms of the build-own-transfer agreement, including both cost and schedule. Negotiations are ongoing, but at this time the project is not expected to achieve commercial operation in 2023.

Driver Solar Facility

In April 2022, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 250 MW Driver Solar Facility is in the public interest. The acquisition of Driver Solar will be contingent upon receiving all necessary regulatory and Board approvals. Entergy Arkansas requested a decision by the APSC by June 2022 and requested cost recovery through the formula rate plan rider. The APSC established a procedural schedule with a hearing scheduled in June 2022. The facility is expected to be in service by the end of 2024.

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Management's Financial Discussion and Analysis

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery.  The following are updates to that discussion.

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Arkansas’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING REVENUES
Electric	$558,956	$583,386
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	86,225	126,181
Purchased power	57,471	70,221
Nuclear refueling outage expenses	14,070	12,647
Other operation and maintenance	157,257	154,908
Decommissioning	20,129	19,000
Taxes other than income taxes	33,202	29,743
Depreciation and amortization	95,610	88,279
Other regulatory charges (credits) - net	(20,542)	(37,467)
TOTAL	443,422	463,512
OPERATING INCOME	115,534	119,874
OTHER INCOME
Allowance for equity funds used during construction	3,055	2,993
Interest and investment income	6,320	27,887
Miscellaneous - net	(5,392)	(5,791)
TOTAL	3,983	25,089
INTEREST EXPENSE
Interest expense	36,047	33,786
Allowance for borrowed funds used during construction	(1,214)	(1,290)
TOTAL	34,833	32,496
INCOME BEFORE INCOME TAXES	84,684	112,467
Income taxes	19,117	19,430
NET INCOME	65,567	93,037
Net loss attributable to noncontrolling interest	(1,387)	—
EARNINGS APPLICABLE TO MEMBER'S EQUITY	$66,954	$93,037
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING ACTIVITIES
Net income	$65,567	$93,037
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	133,634	126,630
Deferred income taxes, investment tax credits, and non-current taxes accrued	11,776	42,885
Changes in assets and liabilities:
Receivables	23,583	(56,256)
Fuel inventory	7,199	17,930
Accounts payable	(33,409)	(21,622)
Taxes accrued	27,209	8,365
Interest accrued	32,233	18,837
Deferred fuel costs	(16,954)	(55,704)
Other working capital accounts	3,794	(8,025)
Provisions for estimated losses	(309)	(12,383)
Other regulatory assets	(7,198)	42,388
Other regulatory liabilities	(91,068)	(38,604)
Pension and other postretirement liabilities	(19,852)	(25,116)
Other assets and liabilities	111,221	(40,789)
Net cash flow provided by operating activities	247,426	91,573
INVESTING ACTIVITIES
Construction expenditures	(162,108)	(146,334)
Allowance for equity funds used during construction	3,055	2,993
Nuclear fuel purchases	(27,258)	(17,621)
Proceeds from sale of nuclear fuel	37,157	16,059
Proceeds from nuclear decommissioning trust fund sales	64,608	143,575
Investment in nuclear decommissioning trust funds	(69,950)	(148,783)
Changes in money pool receivable - net	(59,981)	(12,500)
Net cash flow used in investing activities	(214,477)	(162,611)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	212,060	604,760
Retirement of long-term debt	(7,506)	(613,706)
Change in money pool payable - net	(139,904)	—
Other	(483)	11,636
Net cash flow provided by financing activities	64,167	2,690
Net increase (decrease) in cash and cash equivalents	97,116	(68,348)
Cash and cash equivalents at beginning of period	12,915	192,128
Cash and cash equivalents at end of period	$110,031	$123,780
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$3,227	$14,359
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$2,852	$8,155
Temporary cash investments	107,179	4,760
Total cash and cash equivalents	110,031	12,915
Accounts receivable:
Customer	136,178	154,412
Allowance for doubtful accounts	(6,513)	(13,072)
Associated companies	91,621	29,587
Other	43,337	51,064
Accrued unbilled revenues	95,429	101,663
Total accounts receivable	360,052	323,654
Deferred fuel costs	125,767	108,862
Fuel inventory - at average cost	43,693	50,892
Materials and supplies - at average cost	262,292	247,980
Deferred nuclear refueling outage costs	51,655	65,318
Prepayments and other	14,614	14,863
TOTAL	968,104	824,484
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,360,604	1,438,416
Other	791	947
TOTAL	1,361,395	1,439,363
UTILITY PLANT
Electric	13,637,936	13,578,297
Construction work in progress	306,933	241,127
Nuclear fuel	132,841	182,055
TOTAL UTILITY PLANT	14,077,710	14,001,479
Less - accumulated depreciation and amortization	5,539,188	5,472,296
UTILITY PLANT - NET	8,538,522	8,529,183
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	1,696,876	1,689,678
Deferred fuel costs	68,800	68,751
Other	22,042	13,660
TOTAL	1,787,718	1,772,089
TOTAL ASSETS	$12,655,739	$12,565,119
See Notes to Financial Statements.

86

ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies	$46,527	$217,310
Other	187,777	190,476
Customer deposits	95,178	92,511
Taxes accrued	116,799	89,590
Interest accrued	49,341	17,108
Other	40,881	38,901
TOTAL	536,503	645,896
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,436,824	1,416,201
Accumulated deferred investment tax credits	28,998	29,299
Regulatory liability for income taxes - net	427,203	431,655
Other regulatory liabilities	656,698	743,314
Decommissioning	1,410,540	1,390,410
Accumulated provisions	76,775	77,084
Pension and other postretirement liabilities	165,903	185,789
Long-term debt	4,163,602	3,958,862
Other	111,271	110,754
TOTAL	8,477,814	8,343,368
Commitments and Contingencies
EQUITY
Member's equity	3,609,699	3,542,745
Noncontrolling interest	31,723	33,110
TOTAL	3,641,422	3,575,855
TOTAL LIABILITIES AND EQUITY	$12,655,739	$12,565,119
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	Noncontrolling Interest	Member's Equity	Total
	(In Thousands)
Balance at December 31, 2020	$—	$3,276,169	$3,276,169
Net income	—	93,037	93,037
Balance at March 31, 2021	$—	$3,369,206	$3,369,206
Balance at December 31, 2021	$33,110	$3,542,745	$3,575,855
Net income (loss)	(1,387)	66,954	65,567
Balance at March 31, 2022	$31,723	$3,609,699	$3,641,422
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Net income decreased $15.8 million primarily due to higher other operation and maintenance expenses, higher interest expense, higher taxes other than income taxes, higher depreciation and amortization expenses, and lower volume/weather. The decrease was partially offset by higher retail electric price.

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2022 to the first quarter 2021:

	Amount
	(In Millions)
2021 operating revenues	$1,107.6
Fuel, rider, and other revenues that do not significantly affect net income	153.5
Retail electric price	17.2
Volume/weather	(12.3)
2022 operating revenues	$1,266.0

Entergy Louisiana’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to an increase in formula rate plan revenues, including increases in the transmission and distribution recovery mechanisms, effective September 2021. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan proceedings.

The volume/weather variance is primarily due to the effect of less favorable weather on residential sales and a decrease in weather-adjusted residential usage, including the effect of the COVID-19 pandemic on first quarter 2021, partially offset by increases in industrial and commercial usage. The increase in industrial usage was primarily due to increased demand from expansion projects, primarily in the chemicals, petroleum refining, and transportation industries, increased demand from existing customers, primarily in the chemicals and pulp and paper industries as a result of prior year temporary plant shutdowns and operational issues, and an increase in demand from cogeneration customers. The increase in commercial usage was primarily due to the effect of the COVID-19 pandemic on businesses in first quarter 2021. The increased usage from these industrial and commercial customers has a relatively smaller effect on operating revenues because a larger portion of the revenues from those customers comes from fixed charges.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Total electric energy sales for Entergy Louisiana for the three months ended March 31, 2022 and 2021 are as follows:

	2022	2021	% Change
	(GWh)
Residential	3,069	3,197	(4)
Commercial	2,421	2,395	1
Industrial	7,606	7,208	6
Governmental	191	196	(3)
Total retail	13,287	12,996	2
Sales for resale:
Associated companies	1,341	959	40
Non-associated companies	853	386	121
Total	15,481	14,341	8

See Note 13 to the financial statements herein for additional discussion of Entergy Louisiana’s operating revenues.

Other Income Statement Variances

Other operation and maintenance expenses increased primarily due to:

•an increase of $7.3 million in distribution operations expenses primarily due to higher reliability costs, higher safety and training costs, and higher vegetation maintenance costs, partially offset by a decrease in meter reading expenses as a result of the deployment of advanced metering systems;

•an increase of $2.6 million in nuclear generation expenses primarily due to a higher scope of work performed in 2022 as compared to prior year, partially offset by lower spending in 2022 on sanitation and social distancing protocols as a result of the COVID-19 pandemic;

•an increase of $2.3 million in transmission expenses, including an increase in vegetation maintenance costs; and

•an increase of $2.3 million in customer service center support costs primarily due to higher contract costs.

The increase was partially offset by higher nuclear insurance refunds of $2.6 million and a decrease of $2.6 million in non-nuclear generation expenses primarily due to a lower scope of work performed in 2022 as compared to the same period in 2021.

Taxes other than income taxes increased primarily due to increases in ad valorem taxes resulting from higher assessments and increases in franchise taxes.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other income decreased primarily due to changes in decommissioning trust fund activity, including portfolio rebalancing of the Waterford 3 and River Bend decommissioning trust funds in the first quarter of 2021.

Interest expense increased primarily due to:

•the issuances of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;

•the $1.2 billion unsecured term loan proceeds received in January 2022; and

•the issuance of $1 billion of 0.95% Series mortgage bonds in October 2021.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

The increase was partially offset by the repayment of $200 million of 4.8% Series mortgage bonds in May 2021.

Income Taxes

The effective income tax rates were 16.9% for the first quarter 2022 and 18.5% for the first quarter 2021. The differences in the effective income tax rates for the first quarter 2022 and the first quarter 2021 versus the federal statutory rate of 21% were primarily due to book and tax differences related to the non-taxable income distributions earned on preferred membership interests, certain book and tax differences related to utility plant items, and the amortization of excess accumulated deferred income taxes, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Cash and cash equivalents at beginning of period	$18,573	$728,020
Net cash provided by (used in):
Operating activities	183,126	(54,598)
Investing activities	(1,032,121)	(1,098,466)
Financing activities	987,069	1,026,860
Net increase (decrease) in cash and cash equivalents	138,074	(126,204)
Cash and cash equivalents at end of period	$156,647	$601,816

Operating Activities

Entergy Louisiana’s operating activities provided $183.1 million of cash for the three months ended March 31, 2022 compared to using $54.6 million of cash for the three months ended March 31, 2021 primarily due to the following activity:

•higher collections from customers;

•timing of recovery of fuel and purchased power costs;

•a decrease of $20 million in spending on nuclear refueling outages; and

•a decrease of $18.9 million in pension contributions in 2022. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

The above activity was partially offset by an increase of approximately $139 million in storm spending in 2022, primarily due to Hurricane Ida restoration efforts. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K for discussion of storm restoration efforts.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Investing Activities

Net cash flow used in investing activities decreased $66.3 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•a decrease of $60.9 million in transmission construction expenditures primarily due to higher capital expenditures for storm restoration in 2021;

•a decrease of $24.9 million in nuclear decommissioning trust fund activity as a result of a lump sum contribution in 2021 for amounts collected over a 17-month period. See Note 2 in the Form 10-K for a discussion of nuclear decommissioning expense recovery; and

•a decrease of $23.2 million as a result of fluctuations in nuclear fuel activity, primarily due to variations from year to year in the timing and pricing of fuel reload requirements, materials and services deliveries, and the timing of cash payments during the nuclear fuel cycle.

The decrease was partially offset by:

•an increase of $35.1 million in distribution construction expenditures primarily due to higher capital expenditures for storm restoration in 2022, partially offset by lower spending in 2022 on advanced metering infrastructure;

•an increase of $11.1 million in information technology capital expenditures primarily due to increased spending on various technology projects in 2022; and

•an increase of $9 million in nuclear construction expenditures primarily due to higher capital expenditures for storm restoration in 2022.

Financing Activities

Net cash flow provided by financing activities decreased $39.8 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;

•net repayments of long-term borrowings of $30.6 million in 2022 compared to net long-term borrowings of $85.5 million in 2021 on the nuclear fuel company variable interest entities’ credit facilities; and

•$125 million in common equity distributions in 2022 to return to Entergy Corporation the $125 million capital contribution received in December 2021 to assist in paying for costs associated with Hurricane Ida.

The decrease was partially offset by the $1.2 billion of proceeds received from an unsecured term loan in January 2022 and the repayment of Entergy Louisiana Waterford VIE’s $40 million of 3.92% Series H secured notes in February 2021.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

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Management's Financial Discussion and Analysis

Capital Structure

Entergy Louisiana’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy Louisiana is primarily due to the $1.2 billion unsecured term loan proceeds received in January 2022.

	March 31, 2022		December 31, 2021
Debt to capital	59.5	%	57.2	%
Effect of subtracting cash	(0.3	%)	0.0	%
Net debt to net capital	59.2	%	57.2	%

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings, finance lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Louisiana uses the debt to capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition. Entergy Louisiana also uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because net debt indicates Entergy Louisiana’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Louisiana’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Louisiana’s receivables from or (payables to) the money pool were as follows:

March 31, 2022	December 31, 2021	March 31, 2021	December 31, 2020
(In Thousands)
$81,160	$14,539	$75,772	$13,426

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Louisiana has a credit facility in the amount of $350 million scheduled to expire in June 2026.  The credit facility includes fronting commitments for the issuance of letters of credit against $15 million of the borrowing capacity of the facility. As of March 31, 2022, there were no cash borrowings and no letters of credit outstanding under the credit facility.  In addition, Entergy Louisiana is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of March 31, 2022, $11 million in letters of credit were outstanding under Entergy Louisiana’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

The Entergy Louisiana nuclear fuel company variable interest entities have two separate credit facilities, each in the amount of $105 million and scheduled to expire in June 2024.  As of March 31, 2022, $30.8 million in loans were outstanding under the credit facility for the Entergy Louisiana River Bend nuclear fuel company variable interest entity. As of March 31, 2022, $82.1 million in loans were outstanding under the credit facility for the Entergy Louisiana Waterford nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facilities.

See the table and discussion in the Form 10-K under “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Uses of Capital,” that sets forth the amounts of planned

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Management's Financial Discussion and Analysis

construction and other capital investments for 2022 through 2024. While Entergy Louisiana is still assessing the effect on its planned solar projects, a recently commenced investigation by the U.S. Department of Commerce into potential circumvention of duties and tariffs may result in increased duties or tariffs on imported solar panels and has created supply chain disruptions which will affect the ultimate timing and could increase the cost of completion of these projects.

2021 Solar Certification and the Geaux Green Option

As discussed in the Form 10-K, in November 2021, Entergy Louisiana filed an application with the LPSC seeking certification of and approval for the addition of four new solar photovoltaic resources with a combined nameplate capacity of 475 megawatts (the 2021 Solar Portfolio) and the implementation of a new green tariff, the Geaux Green Option (Rider GGO). The LPSC has established a procedural schedule that is expected to result in an LPSC decision by the end of 2022. In March 2022 direct testimony from Walmart, the Louisiana Energy Users Group (LEUG) and the LPSC staff was filed. Each party recommended that the LPSC approve the resources proposed in Entergy Louisiana’s application, and the LPSC staff witness indicated that the process through which Entergy Louisiana solicited or obtained the proposals for the resources complies with applicable LPSC orders. LPSC staff and LEUG’s witnesses made recommendations to modify the proposed Rider GGO and Entergy Louisiana’s proposed rate relief. In April 2022, LPSC staff and LEUG filed cross-answering testimony concerning the other party’s proposed modifications to Rider GGO and the proposed rate recovery. Discovery concerning these parties’ testimonies is ongoing.

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application, currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel cost recovery. The following are updates to that discussion.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Louisiana’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING REVENUES
Electric	$1,237,237	$1,079,663
Natural gas	28,735	27,981
TOTAL	1,265,972	1,107,644
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	362,074	145,234
Purchased power	176,197	209,961
Nuclear refueling outage expenses	11,947	13,282
Other operation and maintenance	254,001	237,483
Decommissioning	17,688	16,823
Taxes other than income taxes	61,615	52,484
Depreciation and amortization	169,083	160,813
Other regulatory charges (credits) - net	(20,897)	31,097
TOTAL	1,031,708	867,177
OPERATING INCOME	234,264	240,467
OTHER INCOME
Allowance for equity funds used during construction	6,726	6,101
Interest and investment income	15,900	72,515
Miscellaneous - net	15,517	(34,638)
TOTAL	38,143	43,978
INTEREST EXPENSE
Interest expense	93,784	82,806
Allowance for borrowed funds used during construction	(3,026)	(2,759)
TOTAL	90,758	80,047
INCOME BEFORE INCOME TAXES	181,649	204,398
Income taxes	30,789	37,772
NET INCOME	$150,860	$166,626
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
Net Income	$150,860	$166,626
Other comprehensive loss
Pension and other postretirement liabilities (net of tax benefit of $226 and $144)	(613)	(407)
Other comprehensive loss	(613)	(407)
Comprehensive Income	$150,247	$166,219
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING ACTIVITIES
Net income	$150,860	$166,626
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	213,022	198,868
Deferred income taxes, investment tax credits, and non-current taxes accrued	95,785	67,823
Changes in working capital:
Receivables	71,237	(13,080)
Fuel inventory	(46)	1,194
Accounts payable	(262,042)	(126,070)
Taxes accrued	(42,950)	20,619
Interest accrued	(857)	(9,163)
Deferred fuel costs	498	(203,815)
Other working capital accounts	(24,241)	(25,628)
Changes in provisions for estimated losses	2,694	(258)
Changes in other regulatory assets	(1,336,616)	(70,784)
Changes in other regulatory liabilities	(67,164)	22,503
Storm restoration costs approved for securitization recognized as regulatory asset	1,338,559	—
Changes in pension and other postretirement liabilities	(11,608)	(30,745)
Other	55,995	(52,688)
Net cash flow provided by (used in) operating activities	183,126	(54,598)
INVESTING ACTIVITIES
Construction expenditures	(935,692)	(945,831)
Allowance for equity funds used during construction	6,726	6,101
Nuclear fuel purchases	(55,913)	(52,435)
Proceeds from the sale of nuclear fuel	26,681	—
Changes to securitization account	—	(6,050)
Proceeds from nuclear decommissioning trust fund sales	155,269	291,275
Investment in nuclear decommissioning trust funds	(168,283)	(329,180)
Changes in money pool receivable - net	(66,621)	(62,346)
Litigation proceeds from settlement agreement	5,695	—
Other	17	—
Net cash flow used in investing activities	(1,032,121)	(1,098,466)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,506,637	1,399,245
Retirement of long-term debt	(401,411)	(368,707)
Distributions paid:
Common equity	(125,000)	—
Other	6,843	(3,678)
Net cash flow provided by financing activities	987,069	1,026,860
Net increase (decrease) in cash and cash equivalents	138,074	(126,204)
Cash and cash equivalents at beginning of period	18,573	728,020
Cash and cash equivalents at end of period	$156,647	$601,816
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$91,441	$89,432
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$15,933	$195
Temporary cash investments	140,714	18,378
Total cash and cash equivalents	156,647	18,573
Accounts receivable:
Customer	256,931	355,265
Allowance for doubtful accounts	(11,092)	(29,231)
Associated companies	159,787	96,539
Other	49,735	36,674
Accrued unbilled revenues	174,038	174,768
Total accounts receivable	629,399	634,015
Deferred fuel costs	44,876	45,374
Fuel inventory	43,004	42,958
Materials and supplies - at average cost	490,752	485,325
Deferred nuclear refueling outage costs	33,947	39,582
Prepayments and other	58,384	44,187
TOTAL	1,457,009	1,310,014
OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests	1,390,587	1,390,587
Decommissioning trust funds	2,005,369	2,114,523
Non-utility property - at cost (less accumulated depreciation)	338,365	337,247
Other	13,812	13,744
TOTAL	3,748,133	3,856,101
UTILITY PLANT
Electric	27,252,039	28,055,038
Natural gas	288,820	285,006
Construction work in progress	721,536	847,924
Nuclear fuel	200,163	209,418
TOTAL UTILITY PLANT	28,462,558	29,397,386
Less - accumulated depreciation and amortization	9,940,422	9,860,252
UTILITY PLANT - NET	18,522,136	19,537,134
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	4,113,282	2,776,666
Deferred fuel costs	168,122	168,122
Other	39,358	27,801
TOTAL	4,320,762	2,972,589
TOTAL ASSETS	$28,048,040	$27,675,838
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$200,000	$200,000
Accounts payable:
Associated companies	81,781	183,172
Other	872,120	1,481,902
Customer deposits	153,109	150,697
Taxes accrued	21,298	64,248
Interest accrued	92,195	93,052
Current portion of unprotected excess accumulated deferred income taxes	15,182	24,291
Other	56,709	68,995
TOTAL	1,492,394	2,266,357
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,523,361	2,433,854
Accumulated deferred investment tax credits	101,408	102,588
Regulatory liability for income taxes - net	307,779	313,693
Other regulatory liabilities	990,456	1,042,597
Decommissioning	1,673,809	1,653,198
Accumulated provisions	27,185	24,490
Pension and other postretirement liabilities	516,628	528,213
Long-term debt	11,822,131	10,714,346
Other	387,083	415,930
TOTAL	18,349,840	17,228,909
Commitments and Contingencies
EQUITY
Member's equity	8,198,141	8,172,294
Accumulated other comprehensive income	7,665	8,278
TOTAL	8,205,806	8,180,572
TOTAL LIABILITIES AND EQUITY	$28,048,040	$27,675,838
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	Common Equity
	Member’s Equity	Accumulated Other Comprehensive Income	Total
	(In Thousands)
Balance at December 31, 2020	$7,453,361	$4,327	$7,457,688
Net income	166,626	—	166,626
Other comprehensive loss	—	(407)	(407)
Other	(16)	—	(16)
Balance at March 31, 2021	$7,619,971	$3,920	$7,623,891
Balance at December 31, 2021	$8,172,294	$8,278	$8,180,572
Net income	150,860	—	150,860
Other comprehensive loss	—	(613)	(613)
Distributions declared on common equity	(125,000)	—	(125,000)
Other	(13)	—	(13)
Balance at March 31, 2022	$8,198,141	$7,665	$8,205,806
See Notes to Financial Statements.

102

ENTERGY MISSISSIPPI, LLC

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Net income increased $4.4 million primarily due to higher retail electric price, partially offset by higher depreciation and amortization expenses and higher interest expenses.

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2022 to the first quarter 2021:

	Amount
	(In Millions)
2021 operating revenues	$336.6
Fuel, rider, and other revenues that do not significantly affect net income	(2.2)
Retail electric price	16.4
Volume/weather	(1.8)
2022 operating revenues	$349.0

Entergy Mississippi’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to increases in formula rate plan rates effective April 2021 and July 2021. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filings.

The volume/weather variance is primarily due to a decrease in weather-adjusted residential usage, including the effect of the COVID-19 pandemic on first quarter 2021, partially offset by the effect of more favorable weather on residential and commercial sales.

103

Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Total electric energy sales for Entergy Mississippi for the three months ended March 31, 2022 and 2021 are as follows:

	2022	2021	% Change
	(GWh)
Residential	1,295	1,349	(4)
Commercial	1,021	1,004	2
Industrial	561	527	6
Governmental	96	95	1
Total retail	2,973	2,975	—
Sales for resale:
Non-associated companies	535	1,452	(63)
Total	3,508	4,427	(21)

See Note 13 to the financial statements herein for additional discussion of Entergy Mississippi’s operating revenues.

Other Income Statement Variances

Taxes other than income taxes increased primarily due to increases in ad valorem taxes resulting from higher assessments and millage rate increases.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Interest expense increased primarily due to the issuance of $200 million of 3.50% Series mortgage bonds in March 2021 and the issuance of $200 million of 2.55% Series mortgage bonds in November 2021.

Income Taxes

The effective income tax rates were 20.2% for the first quarter 2022 and 22.2% for the first quarter 2021. The differences in the effective income tax rates for the first quarter 2022 and the first quarter 2021 versus the federal statutory rate of 21% were primarily due to certain book and tax differences related to utility plant items, partially offset by state income taxes.

104

Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Cash and cash equivalents at beginning of period	$47,627	$18
Net cash provided by (used in):
Operating activities	(4,340)	54,311
Investing activities	(61,154)	(162,802)
Financing activities	17,895	185,189
Net increase (decrease) in cash and cash equivalents	(47,599)	76,698
Cash and cash equivalents at end of period	$28	$76,716

Operating Activities

Entergy Mississippi’s operating activities used $4.3 million of cash for the three months ended March 31, 2022 compared to providing $54.3 million of cash for the three months ended March 31, 2021 primarily due to the following activity:

•timing of payments to vendors;

•income tax refunds of $8 million received in 2021 in accordance with an intercompany income tax allocation agreement;

•higher collections from customers; and

•a decrease of $7.2 million in storm spending in 2022 primarily due to spending on Winter Storm Uri restoration efforts in 2021.

Investing Activities

Net cash flow used in investing activities decreased $101.6 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•a decrease of $51.3 million in distribution construction expenditures primarily due to a higher scope of work performed in 2021 as compared to 2022; and

•money pool activity.

Decreases in Entergy Mississippi’s receivable from the money pool are a source of cash flow, and Entergy Mississippi’s receivable from the money pool decreased by $40.5 million for the three months ended March 31, 2022 compared to increasing $9.7 million for the three months ended March 31, 2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility’s subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities decreased $167.3 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to the issuance of $200 million of 3.50% Series mortgage bonds in March 2021, partially offset by money pool activity.

105

Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Increases in Entergy Mississippi’s payable to the money pool are a source of cash flow and Entergy Mississippi’s payable to the money pool increased by $22.4 million for the three months ended March 31, 2022 compared to decreasing by $16.5 million for the three months ended March 31, 2021.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Mississippi’s debt to capital ratio is shown in the following table.

	March 31,  2022		December 31, 2021
Debt to capital	53.9	%	54.3	%
Effect of subtracting cash	—	%	(0.5	%)
Net debt to net capital	53.9	%	53.8	%

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, finance lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Mississippi uses the debt to capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi’s financial condition.  Entergy Mississippi also uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi’s financial condition because net debt indicates Entergy Mississippi’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Mississippi’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Mississippi’s receivables from or (payables to) the money pool were as follows:

March 31,  2022	December 31, 2021	March 31,  2021	December 31, 2020
(In Thousands)
($22,386)	$40,456	$9,683	($16,516)

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

As of March 31, 2022, Entergy Mississippi had three separate credit facilities in the aggregate amount of $82.5 million scheduled to expire in April 2022. No borrowings were outstanding under the credit facilities as of March 31, 2022. In April 2022, Entergy Mississippi renewed the three separate existing credit facilities and increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a credit facility in the amount of $150 million with an expiration date of July 2024. In addition, Entergy Mississippi is a party to an uncommitted letter of credit facility primarily as a means to post collateral to support its obligations to MISO. As of March 31, 2022, $2.3 million in MISO letters of credit and $1 million in non-MISO letters of credit were outstanding under this facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

106

Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Entergy Mississippi had $33.2 million in its storm reserve escrow account at March 31, 2022.

Sunflower Solar Facility

As discussed in the Form 10-K, in November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW solar photovoltaic facility that will be sited on approximately 1,000 acres in Sunflower County, Mississippi. The estimated total investment, including the base purchase price and other related costs, for Entergy Mississippi to acquire the Sunflower Solar Facility is approximately $153.2 million. Entergy Mississippi will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar Facility and its recovery through Entergy Mississippi’s interim capacity rate adjustment mechanism, subject to certain conditions including: (i) that Entergy Mississippi pursue a partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement, and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar Facility. The initial closing is targeted to occur in May 2022. In conjunction with closing, Entergy Mississippi is executing a partnership structure through which the partnership will acquire and own the Sunflower Solar Facility. Final payment of the purchase price will be made upon substantial completion of the facility, which is currently expected in third quarter 2022.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of the formula rate plan and fuel and purchased power cost recovery. The following are updates to that discussion.

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

107

Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Mississippi’s accounting for utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

108

ENTERGY MISSISSIPPI, LLC
INCOME STATEMENTS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING REVENUES
Electric	$349,029	$336,619
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	67,277	60,197
Purchased power	61,212	68,591
Other operation and maintenance	65,811	67,831
Taxes other than income taxes	32,730	25,899
Depreciation and amortization	60,084	55,036
Other regulatory charges (credits) - net	3,907	8,129
TOTAL	291,021	285,683
OPERATING INCOME	58,008	50,936
OTHER DEDUCTIONS
Allowance for equity funds used during construction	1,078	1,668
Interest and investment income	64	42
Miscellaneous - net	(1,153)	(2,313)
TOTAL	(11)	(603)
INTEREST EXPENSE
Interest expense	20,434	17,613
Allowance for borrowed funds used during construction	(465)	(677)
TOTAL	19,969	16,936
INCOME BEFORE INCOME TAXES	38,028	33,397
Income taxes	7,673	7,425
NET INCOME	$30,355	$25,972
See Notes to Financial Statements.

109

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110

ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING ACTIVITIES
Net income	$30,355	$25,972
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation and amortization	60,084	55,036
Deferred income taxes, investment tax credits, and non-current taxes accrued	3,979	22,593
Changes in assets and liabilities:
Receivables	(6,379)	4,557
Fuel inventory	23	1,736
Accounts payable	989	26,391
Taxes accrued	(63,785)	(75,886)
Interest accrued	10,613	4,238
Deferred fuel costs	(24,076)	(25,722)
Other working capital accounts	(46,494)	(3,425)
Provisions for estimated losses	(179)	(7,689)
Other regulatory assets	16,301	11,015
Other regulatory liabilities	21,689	19,147
Pension and other postretirement liabilities	(3,906)	(5,668)
Other assets and liabilities	(3,554)	2,016
Net cash flow provided by (used in) operating activities	(4,340)	54,311
INVESTING ACTIVITIES
Construction expenditures	(102,686)	(154,788)
Allowance for equity funds used during construction	1,078	1,668
Changes in money pool receivable - net	40,456	(9,683)
Other	(2)	1
Net cash flow used in investing activities	(61,154)	(162,802)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—	200,573
Changes in money pool payable - net	22,386	(16,516)
Other	(4,491)	1,132
Net cash flow provided by financing activities	17,895	185,189
Net increase (decrease) in cash and cash equivalents	(47,599)	76,698
Cash and cash equivalents at beginning of period	47,627	18
Cash and cash equivalents at end of period	$28	$76,716
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$9,160	$12,757
Income taxes	$—	($8,045)
See Notes to Financial Statements.

111

ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
ASSETS
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$26	$29
Temporary cash investments	2	47,598
Total cash and cash equivalents	28	47,627
Accounts receivable:
Customer	86,389	84,048
Allowance for doubtful accounts	(3,396)	(7,209)
Associated companies	5,008	42,994
Other	17,994	14,609
Accrued unbilled revenues	50,404	56,034
Total accounts receivable	156,399	190,476
Deferred fuel costs	145,954	121,878
Fuel inventory - at average cost	10,288	10,311
Materials and supplies - at average cost	75,509	69,639
Prepayments and other	40,847	6,394
TOTAL	429,025	446,325
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,523	4,527
Escrow accounts	48,888	48,886
TOTAL	53,411	53,413
UTILITY PLANT
Electric	6,650,580	6,613,109
Construction work in progress	120,538	95,452
TOTAL UTILITY PLANT	6,771,118	6,708,561
Less - accumulated depreciation and amortization	2,159,949	2,127,590
UTILITY PLANT - NET	4,611,169	4,580,971
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	446,131	462,432
Other	18,880	14,248
TOTAL	465,011	476,680
TOTAL ASSETS	$5,558,616	$5,557,389
See Notes to Financial Statements.

112

ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies	$62,229	$42,929
Other	104,367	113,000
Customer deposits	87,307	86,167
Taxes accrued	42,488	106,273
Interest accrued	27,896	17,283
Other	29,735	36,731
TOTAL	354,022	402,383
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	724,154	720,097
Accumulated deferred investment tax credits	10,857	10,913
Regulatory liability for income taxes - net	209,758	212,445
Other regulatory liabilities	73,689	49,313
Asset retirement cost liabilities	10,458	10,315
Accumulated provisions	37,849	38,028
Pension and other postretirement liabilities	55,101	59,065
Long-term debt	2,180,197	2,179,989
Other	32,608	35,273
TOTAL	3,334,671	3,315,438
Commitments and Contingencies
EQUITY
Member's equity	1,869,923	1,839,568
TOTAL	1,869,923	1,839,568
TOTAL LIABILITIES AND EQUITY	$5,558,616	$5,557,389
See Notes to Financial Statements.

113

ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	Member's Equity
	(In Thousands)
Balance at December 31, 2020	$1,672,734
Net income	25,972
Balance at March 31, 2021	$1,698,706
Balance at December 31, 2021	$1,839,568
Net income	30,355
Balance at March 31, 2022	$1,869,923
See Notes to Financial Statements.

114

ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Net income increased $13.4 million primarily due to higher retail electric price and lower other operation and maintenance expenses.

Operating Revenues

Following is an analysis of the change in operating revenues comparing first quarter 2022 to first quarter 2021:

	Amount
	(In Millions)
2021 operating revenues	$169.3
Fuel, rider, and other revenues that do not significantly affect net income	15.9
Retail electric price	10.3
Volume/weather	2.8
2022 operating revenues	$198.3

Entergy New Orleans’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to a rate increase effective November 2021 in accordance with the terms of the 2021 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.

The volume/weather variance is primarily due to an increase in commercial usage. The increase in commercial usage was primarily due to the effect of the COVID-19 pandemic on businesses in first quarter 2021.

115

Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Total electric energy sales for Entergy New Orleans for the three months ended March 31, 2022 and 2021 are as follows:

	2022	2021	% Change
	(GWh)
Residential	538	538	—
Commercial	465	446	4
Industrial	94	94	—
Governmental	178	172	3
Total retail	1,275	1,250	2
Sales for resale:
Non-associated companies	716	89	704
Total	1,991	1,339	49

See Note 13 to the financial statements herein for additional discussion of Entergy New Orleans’s operating revenues.

Other Income Statement Variances

Other operation and maintenance expenses decreased primarily due to a decrease of $2.4 million in non-nuclear generation expenses primarily due to the timing of the scope of work performed during plant outages in 2022 as compared to the same period in 2021 and a decrease of $2 million in energy efficiency expenses due to the timing of recovery from customers.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Interest expense increased primarily due to the issuance of $90 million of 4.19% Series mortgage bonds and the issuance of $70 million of 4.51% Series mortgage bonds, each in November 2021.

Income Taxes

The effective income tax rate was 17.8% for first quarter 2022. The difference in the effective income tax rate for first quarter 2022 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects of and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 33.9% for first quarter 2021. The difference in the effective income tax rate for first quarter 2021 versus the federal statutory rate of 21% was primarily due to the provision for uncertain tax positions and state income taxes, partially offset by certain book and tax differences related to utility plant items.

116

Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Cash and cash equivalents at beginning of period	$42,862	$26
Net cash provided by (used in):
Operating activities	41,811	(14,114)
Investing activities	(53,401)	14,875
Financing activities	(107)	14,825
Net increase (decrease) in cash and cash equivalents	(11,697)	15,586
Cash and cash equivalents at end of period	$31,165	$15,612

Operating Activities

Entergy New Orleans’s operating activities provided $41.8 million of cash for the three months ended March 31, 2022 compared to using $14.1 million of cash for the three months ended March 31, 2021 primarily due to the following activity:

•higher collections from customers;

•the timing of payments to vendors;

•an increase of $9.3 million in storm spending in 2022, primarily due to Hurricane Ida restoration efforts. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K for discussion of hurricane restoration efforts; and

•the timing of recovery of fuel and purchased power costs.

Investing Activities

Entergy New Orleans’s investing activities used $53.4 million of cash for the three months ended March 31, 2022 compared to providing $14.9 million of cash for the three months ended March 31, 2021 primarily due to the following activity:

•an increase of $50.2 million in distribution construction expenditures primarily due to higher capital expenditures for storm restoration in 2022. The increase in storm restoration spending is primarily due to Hurricane Ida restoration efforts. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K for discussion of hurricane restoration efforts;

•$44.2 million in receipts from storm reserve escrow accounts in 2021; and

•money pool activity.

Decreases in Entergy New Orleans’s receivable from the money pool are a source of cash flow, and Entergy New Orleans’s receivable from the money pool decreased $18.3 million for the three months ended March 31, 2022. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

117

Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Financing Activities

Entergy New Orleans’s financing activities used $0.1 million of cash for the three months ended March 31, 2022 compared to providing $14.8 million of cash for the three months ended March 31, 2021 primarily due to money pool activity.

Increases in Entergy New Orleans’s payable to the money pool are a source of cash flow, and Entergy New Orleans’s payable to the money pool increased $15 million for the three months ended March 31, 2021.

Capital Structure

Entergy New Orleans’s debt to capital ratio is shown in the following table.

	March 31, 2022		December 31, 2021
Debt to capital	54.8	%	55.4	%
Effect of excluding securitization bonds	(1.0	%)	(1.0	%)
Debt to capital, excluding securitization bonds (a)	53.8	%	54.4	%
Effect of subtracting cash	(1.0	%)	(1.4	%)
Net debt to net capital, excluding securitization bonds (a)	52.8	%	53.0	%

(a)Calculation excludes the securitization bonds, which are non-recourse to Entergy New Orleans.

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings, finance lease obligations, long-term debt, including the currently maturing portion, and the long-term payable due to an associated company. Capital consists of debt and equity. Net capital consists of capital less cash and cash equivalents. Entergy New Orleans uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because the securitization bonds are non-recourse to Entergy New Orleans, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy New Orleans also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because net debt indicates Entergy New Orleans’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy New Orleans’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.  

Entergy New Orleans’s receivables from or (payables to) the money pool were as follows:

March 31, 2022	December 31, 2021	March 31, 2021	December 31, 2020
(In Thousands)
$18,122	$36,410	($25,229)	($10,190)

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

118

Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Entergy New Orleans has a credit facility in the amount of $25 million scheduled to expire in June 2024. The credit facility includes fronting commitments for the issuance of letters of credit against $10 million of the borrowing capacity of the facility. As of March 31, 2022, no cash borrowings and no letters of credit were outstanding under the facility. In addition, Entergy New Orleans is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of March 31, 2022, a $1 million letter of credit was outstanding under Entergy New Orleans’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. A City Council decision is expected in third quarter 2022.

Hurricane Ida

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Ida” in the Form 10-K for a discussion of Hurricane Ida, which caused significant damage to Entergy New Orleans’s service area, including Entergy’s electrical grid. Entergy New Orleans expects to initiate its storm cost recovery proceeding in late second quarter 2022.

State and Local Rate Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation” in the Form 10-K for a discussion of state and local rate regulation. The following are updates to that discussion.

Retail Rates

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

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Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Reliability Investigation

As discussed in the Form 10-K, in April 2018 the City Council adopted a resolution directing Entergy New Orleans to demonstrate that it has been prudent in the management and maintenance of the reliability of its distribution system. The City Council also approved a resolution that opened a prudence investigation into whether Entergy New Orleans was imprudent for not acting sooner to address outages in New Orleans and whether fines should be imposed. In January 2019, Entergy New Orleans filed testimony in response to the prudence investigation and asserting that it had been prudent in managing system reliability. In April 2019 the City Council advisors filed comments and testimony asserting that Entergy New Orleans did not act prudently in maintaining and improving its distribution system reliability in recent years and recommending that a financial penalty in the range of $1.5 million to $2 million should be assessed.  Entergy New Orleans disagreed with the recommendation and submitted rebuttal testimony and rebuttal comments in June 2019. In November 2019 the City Council passed a resolution that penalized Entergy New Orleans $1 million for alleged imprudence in the maintenance of its distribution system. In December 2019, Entergy New Orleans filed suit in Louisiana state court seeking judicial review of the City Council’s resolution. In March 2022 the Civil District Court approved a scheduling order with briefing through May 2022 and oral argument in June 2022.

System Resiliency and Storm Hardening

As discussed in the Form 10-K, in October 2021 the City Council passed a resolution and order establishing a docket and procedural schedule with respect to system resiliency and storm hardening. The docket will identify a plan for storm hardening and resiliency projects with other stakeholders. In March 2022 the City Council granted Entergy New Orleans’s request for an extension of time to file a response until July 2022.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for further discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy New Orleans’s accounting for utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING REVENUES
Electric	$154,646	$139,148
Natural gas	43,626	30,187
TOTAL	198,272	169,335
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	43,397	19,012
Purchased power	56,470	68,670
Other operation and maintenance	33,652	38,178
Taxes other than income taxes	13,989	12,556
Depreciation and amortization	19,815	18,161
Other regulatory charges (credits) - net	4,185	3,130
TOTAL	171,508	159,707
OPERATING INCOME	26,764	9,628
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	369	258
Interest and investment income	24	9
Miscellaneous - net	(271)	(302)
TOTAL	122	(35)
INTEREST EXPENSE
Interest expense	8,694	7,029
Allowance for borrowed funds used during construction	(199)	(116)
TOTAL	8,495	6,913
INCOME BEFORE INCOME TAXES	18,391	2,680
Income taxes	3,265	909
NET INCOME	$15,126	$1,771
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING ACTIVITIES
Net income	$15,126	$1,771
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation and amortization	19,815	18,161
Deferred income taxes, investment tax credits, and non-current taxes accrued	9,558	4,572
Changes in assets and liabilities:
Receivables	39,328	(1,975)
Fuel inventory	446	2,234
Accounts payable	(14,168)	(27,777)
Taxes accrued	(2,803)	13
Interest accrued	(613)	(3,203)
Deferred fuel costs	(9,959)	(4,886)
Other working capital accounts	(10,876)	(11,103)
Provisions for estimated losses	6,224	(40,680)
Other regulatory assets	25,499	28,879
Other regulatory liabilities	(16,667)	8,728
Pension and other postretirement liabilities	(2,782)	(4,397)
Other assets and liabilities	(16,317)	15,549
Net cash flow provided by (used in) operating activities	41,811	(14,114)
INVESTING ACTIVITIES
Construction expenditures	(68,959)	(26,165)
Allowance for equity funds used during construction	369	258
Changes in money pool receivable - net	18,288	—
Receipts from storm reserve escrow account	—	44,200
Payments to storm reserve escrow account	—	(3)
Changes in securitization account	(3,099)	(3,415)
Net cash flow provided by (used in) investing activities	(53,401)	14,875
FINANCING ACTIVITIES
Changes in money pool payable - net	—	15,039
Other	(107)	(214)
Net cash flow provided by (used in) financing activities	(107)	14,825
Net increase (decrease) in cash and cash equivalents	(11,697)	15,586
Cash and cash equivalents at beginning of period	42,862	26
Cash and cash equivalents at end of period	$31,165	$15,612
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$8,957	$9,921
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$26	$26
Temporary cash investments	31,139	42,836
Total cash and cash equivalents	31,165	42,862
Securitization recovery trust account	5,098	1,999
Accounts receivable:
Customer	61,442	69,902
Allowance for doubtful accounts	(7,702)	(13,282)
Associated companies	21,557	74,146
Other	12,590	13,668
Accrued unbilled revenues	24,481	25,550
Total accounts receivable	112,368	169,984
Deferred fuel costs	2,352	—
Fuel inventory - at average cost	2,499	2,945
Materials and supplies - at average cost	20,610	19,216
Prepayments and other	15,621	5,428
TOTAL	189,713	242,434
OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)	1,016	1,016
TOTAL	1,016	1,016
UTILITY PLANT
Electric	1,964,963	1,976,202
Natural gas	377,826	373,983
Construction work in progress	23,047	22,199
TOTAL UTILITY PLANT	2,365,836	2,372,384
Less - accumulated depreciation and amortization	785,381	774,309
UTILITY PLANT - NET	1,580,455	1,598,075
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs	4,080	4,080
Other regulatory assets (includes securitization property of $22,924 as of March 31, 2022 and $25,761 as of December 31, 2021)	223,118	248,617
Other	60,565	56,101
TOTAL	287,763	308,798
TOTAL ASSETS	$2,058,947	$2,150,323
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT LIABILITIES
Payable due to associated company	$1,326	$1,326
Accounts payable:
Associated companies	41,135	45,057
Other	59,501	146,921
Customer deposits	29,470	28,539
Taxes accrued	1,582	4,385
Interest accrued	7,378	7,991
Deferred fuel costs	—	7,607
Current portion of unprotected excess accumulated deferred income taxes	—	1,906
Other	6,019	6,204
TOTAL	146,411	249,936
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	375,056	365,384
Accumulated deferred investment tax credits	16,297	16,306
Regulatory liability for income taxes - net	39,208	40,589
Asset retirement cost liabilities	—	4,032
Accumulated provisions	12,553	6,329
Long-term debt (includes securitization bonds of $29,721 as of March 31, 2022 and $29,661 as of December 31, 2021)	777,590	777,254
Long-term payable due to associated company	9,585	9,585
Other	28,406	42,193
TOTAL	1,258,695	1,261,672
Commitments and Contingencies
EQUITY
Member's equity	653,841	638,715
TOTAL	653,841	638,715
TOTAL LIABILITIES AND EQUITY	$2,058,947	$2,150,323
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	Member's Equity
	(In Thousands)
Balance at December 31, 2020	$606,917
Net income	1,771
Balance at March 31, 2021	$608,688
Balance at December 31, 2021	$638,715
Net income	15,126
Balance at March 31, 2022	$653,841
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Net income remained relatively unchanged, increasing $0.3 million, primarily due to higher retail electric price, partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2022 to the first quarter 2021:

	Amount
	(In Millions)
2021 operating revenues	$480.2
Fuel, rider, and other revenues that do not significantly affect net income	(28.3)
Volume/weather	0.1
Retail electric price	20.5
2022 operating revenues	$472.5

Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is insignificant and primarily due to an increase in industrial usage, an increase in weather-adjusted commercial usage, and the effect of more favorable weather on residential and commercial sales. The increase in industrial usage was primarily due to an increase in demand from cogeneration and mid-to-small customers and an increase in demand from expansion projects, primarily in the transportation and chemicals industries. The increase in commercial usage was primarily due to an increase in customers and the effect of the COVID-19 pandemic on businesses in first quarter 2021. The increased usage from these industrial and commercial customers has a relatively smaller effect on operating revenues because a larger portion of the revenues from those customers comes from fixed charges.

The retail electric price variance is primarily due to:

•increases in the transmission cost recovery factor rider effective March 2021 and March 2022;

•an increase in the distribution cost recovery factor rider effective January 2022; and

•an increase in the generation cost recovery rider effective January 2022.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the generation cost recovery rider and transmission and distribution cost recovery factor rider filings.

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Management's Financial Discussion and Analysis

Total electric energy sales for Entergy Texas for the three months ended March 31, 2022 and 2021 are as follows:

	2022	2021	% Change
	(GWh)
Residential	1,460	1,394	5
Commercial	1,059	1,004	5
Industrial	2,264	1,963	15
Governmental	64	62	3
Total retail	4,847	4,423	10
Sales for resale:
Associated companies	190	296	(36)
Non-associated companies	144	341	(58)
Total	5,181	5,060	2

See Note 13 to the financial statements herein for additional discussion of Entergy Texas’s operating revenues.

Other Income Statement Variances

Other operation and maintenance expenses increased primarily due to:

•an increase of $7.7 million in non-nuclear generation expenses primarily due to higher expenses associated with the Hardin County Peaking Facility, which was purchased in June 2021, and the Montgomery County Power Station and a higher scope of work performed during outages in 2022 as compared to the same period in 2021;

•an increase of $1.7 million in distribution operations expenses primarily due to higher contractor costs, higher vegetation maintenance costs, and higher safety and training costs; and

•several individually insignificant items.

The increase was partially offset by a decrease of $1.1 million in meter reading expenses as a result of the deployment of advanced metering systems.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Income Taxes

The effective income tax rates were 9.3% for the first quarter 2022 and 9.1% for the first quarter 2021. The differences in the effective income tax rates for the first quarter 2022 and the first quarter 2021 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

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Management's Financial Discussion and Analysis

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Cash and cash equivalents at beginning of period	$28	$248,596
Net cash provided by (used in):
Operating activities	82,338	(28,864)
Investing activities	(144,536)	(223,696)
Financing activities	62,196	3,989
Net decrease in cash and cash equivalents	(2)	(248,571)
Cash and cash equivalents at end of period	$26	$25

Operating Activities

Entergy Texas’s operating activities provided $82.3 million of cash for the three months ended March 31, 2022 compared to using $28.9 million of cash for the three months ended March 31, 2021 primarily due to the following activity:

•the timing of recovery of fuel and purchased power costs, including increased fuel costs in 2021 as a result of Winter Storm Uri. See Note 2 to the financial statements in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•the timing of payments to vendors; and

•higher collections from customers.

Investing Activities

Net cash flow used in investing activities decreased $79.2 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•a decrease of $49 million in distribution construction expenditures primarily due to lower capital expenditures for storm restoration in 2022 and lower spending on advanced metering infrastructure. The decrease in storm restoration spending is primarily due to Hurricane Laura restoration efforts in 2021;

•a decrease of $21.4 million in transmission construction expenditures primarily due to a lower scope of work on projects performed in 2022 as compared to 2021; and

•a decrease of $19.4 million in non-nuclear generation construction expenditures primarily due to a lower scope of work on projects performed in 2022 as compared to 2021.

The decrease was partially offset by cash collateral of $12 million posted in March 2022 to support Entergy Texas’s obligations to MISO.

Financing Activities

Net cash flow provided by financing activities increased $58.2 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to money pool activity.

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Management's Financial Discussion and Analysis

Increases in Entergy Texas’s payable to the money pool are a source of cash flow, and Entergy Texas’s payable to the money pool increased by $91.8 million for the three months ended March 31, 2022 compared to increasing by $30.9 million for the three months ended March 31, 2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Capital Structure

Entergy Texas’s debt to capital ratio is shown in the following table.

	March 31, 2022		December 31, 2021
Debt to capital	47.9	%	48.7	%
Effect of excluding the securitization bonds	(0.2	%)	(0.5	%)
Debt to capital, excluding securitization bonds (a)	47.7	%	48.2	%
Effect of subtracting cash	—	%	—	%
Net debt to net capital, excluding securitization bonds (a)	47.7	%	48.2	%

(a)Calculation excludes the securitization bonds, which are non-recourse to Entergy Texas.

Net debt consists of debt less cash and cash equivalents.  Debt consists of finance lease obligations and long-term debt, including the currently maturing portion.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Texas uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because the securitization bonds are non-recourse to Entergy Texas, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy Texas also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because net debt indicates Entergy Texas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Texas’s uses and sources of capital. Following are updates to information provided in the Form 10-K.

Entergy Texas’s receivables from or (payables to) the money pool were as follows:

March 31, 2022	December 31, 2021	March 31, 2021	December 31, 2020
(In Thousands)
($171,393)	($79,594)	($30,858)	$4,601

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Texas has a credit facility in the amount of $150 million scheduled to expire in June 2026.  The credit facility includes fronting commitments for the issuance of letters of credit against $30 million of the borrowing capacity of the facility. As of March 31, 2022, there were no cash borrowings and $1.3 million of letters of credit outstanding under the credit facility.  In addition, Entergy Texas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of March 31, 2022, $79.6 million in letters of credit were outstanding under Entergy Texas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

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Management's Financial Discussion and Analysis

Orange County Advanced Power Station

As discussed in the Form 10-K, in September 2021, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to construct, own, and operate the Orange County Advanced Power Station, a new 1,215 MW combined-cycle combustion turbine facility to be located in Bridge City, Texas at an initially-estimated expected total cost of $1.2 billion inclusive of the estimated costs of the generation facilities, transmission upgrades, contingency, an allowance for funds used during construction, and necessary regulatory expenses, among others. The project includes combustion turbine technology with dual fuel capability, able to co-fire up to 30% hydrogen by volume upon commercial operation and upgradable to support 100% hydrogen operations in the future. In December 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2022 certain intervenors filed testimony opposing the hydrogen co-firing component of the proposed project and others filed opposing the project outright. Also in March 2022, PUCT staff filed testimony opposing the hydrogen co-firing component of the proposed project, but otherwise taking no specific position on the merits of the project. The PUCT staff also proposed that the PUCT establish a maximum amount that Entergy Texas may recover in rates attributable to the project. In April 2022, Entergy Texas filed rebuttal testimony addressing and rebutting these various arguments. Also in April 2022 the ALJs with the State Office of Administrative Hearings approved a continuance of the hearing on the merits from April 2022 to June 2022, providing Entergy Texas an opportunity to accelerate the determination and fixing of pricing for the Orange County Advanced Power Station prior to the hearing. A final order by the PUCT is expected in third or fourth quarter of 2022. Entergy Texas also is pursuing environmental permitting that is required prior to the commencement of construction. Subject to receipt of required regulatory approvals, permits, and other conditions, the facility is expected to be in service by May 2026.

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery. The following are updates to that discussion.

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Management's Financial Discussion and Analysis

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the

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Management's Financial Discussion and Analysis

appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Green Pricing Option Tariffs

In January 2022, Entergy Texas filed an application requesting approval to implement two voluntary renewable option tariffs, Rider Small Volume Renewable Option (Rider SVRO) and Rider Large Volume Renewable Option (Rider LVRO). Both tariffs are voluntary offerings that give customers the ability to match some or all of their monthly electricity usage with renewable energy credits that are purchased by Entergy Texas and retired on the customer’s behalf. Voluntary participation in either Rider SVRO or Rider LVRO and the charges assessed under the respective tariff would be in addition to the charges paid by customers under their otherwise applicable rate schedules and riders. In April 2022, Entergy Texas filed on behalf of the parties an unopposed settlement agreement supporting approval of Entergy Texas’s proposed green pricing option tariffs. As part of the settlement agreement, Entergy Texas agreed to revise the cost allocation between the rate tiers of Rider SVRO and committed to collaborating with and considering the input of customers to develop an asset-backed green tariff program. This matter is awaiting placement on an open meeting agenda for PUCT consideration of the settlement.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for discussion of nuclear matters.

Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

133

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING REVENUES
Electric	$472,482	$480,220
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	73,920	112,396
Purchased power	161,090	141,362
Other operation and maintenance	74,977	62,955
Taxes other than income taxes	20,449	21,875
Depreciation and amortization	56,061	50,936
Other regulatory charges (credits) - net	13,446	15,840
TOTAL	399,943	405,364
OPERATING INCOME	72,539	74,856
OTHER INCOME
Allowance for equity funds used during construction	2,596	2,445
Interest and investment income	188	224
Miscellaneous - net	307	(423)
TOTAL	3,091	2,246
INTEREST EXPENSE
Interest expense	20,912	23,038
Allowance for borrowed funds used during construction	(865)	(984)
TOTAL	20,047	22,054
INCOME BEFORE INCOME TAXES	55,583	55,048
Income taxes	5,180	4,990
NET INCOME	50,403	50,058
Preferred dividend requirements	518	470
EARNINGS APPLICABLE TO COMMON STOCK	$49,885	$49,588
See Notes to Financial Statements.

134

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING ACTIVITIES
Net income	$50,403	$50,058
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation and amortization	56,061	50,936
Deferred income taxes, investment tax credits, and non-current taxes accrued	(1,175)	(1,522)
Changes in assets and liabilities:
Receivables	(1,674)	(16,424)
Fuel inventory	8,039	3,509
Accounts payable	4,492	(42,511)
Taxes accrued	(15,188)	(5,123)
Interest accrued	(11,195)	(10,989)
Deferred fuel costs	(8,440)	(62,970)
Other working capital accounts	4,832	1,118
Provisions for estimated losses	54	(31)
Other regulatory assets	(135,079)	40,484
Other regulatory liabilities	(11,491)	(13,649)
Storm restoration costs approved for securitization recognized as regulatory asset	153,383	—
Pension and other postretirement liabilities	(4,146)	(5,434)
Other assets and liabilities	(6,538)	(16,316)
Net cash flow provided by (used in) operating activities	82,338	(28,864)
INVESTING ACTIVITIES
Construction expenditures	(155,948)	(238,903)
Allowance for equity funds used during construction	2,596	2,445
Litigation proceeds from settlement agreement	4,134	—
Change in money pool receivable - net	—	4,601
Changes in securitization account	16,631	8,161
Increase in other investments	(11,949)	—
Net cash flow used in investing activities	(144,536)	(223,696)
FINANCING ACTIVITIES
Retirement of long-term debt	(29,064)	(27,951)
Changes in money pool payable - net	91,799	30,858
Preferred stock dividends paid	(505)	(470)
Other	(34)	1,552
Net cash flow provided by financing activities	62,196	3,989
Net decrease in cash and cash equivalents	(2)	(248,571)
Cash and cash equivalents at beginning of period	28	248,596
Cash and cash equivalents at end of period	$26	$25
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$31,513	$33,394
Income taxes	($1,913)	($836)
See Notes to Financial Statements.

135

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents	$26	$28
Securitization recovery trust account	9,998	26,629
Accounts receivable:
Customer	88,964	83,797
Allowance for doubtful accounts	(2,783)	(5,814)
Associated companies	15,868	31,720
Other	23,315	13,404
Accrued unbilled revenues	61,658	62,241
Total accounts receivable	187,022	185,348
Deferred fuel costs	56,720	48,280
Fuel inventory - at average cost	34,673	42,712
Materials and supplies - at average cost	73,415	72,884
Prepayments and other	23,902	17,515
TOTAL	385,756	393,396
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity	287	300
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	17,730	18,128
TOTAL	18,393	18,804
UTILITY PLANT
Electric	7,071,317	7,181,567
Construction work in progress	207,167	183,965
TOTAL UTILITY PLANT	7,278,484	7,365,532
Less - accumulated depreciation and amortization	2,053,212	2,049,750
UTILITY PLANT - NET	5,225,272	5,315,782
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $11,221 as of March 31, 2022 and $23,818 as of December 31, 2021)	556,412	421,333
Other	119,734	112,096
TOTAL	676,146	533,429
TOTAL ASSETS	$6,305,567	$6,261,411
See Notes to Financial Statements.

136

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies	$225,441	$142,929
Other	140,760	164,981
Customer deposits	37,535	37,271
Taxes accrued	33,830	49,018
Interest accrued	7,807	19,002
Current portion of unprotected excess accumulated deferred income taxes	20,059	27,188
Other	15,797	16,120
TOTAL	481,229	456,509
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	695,150	692,496
Accumulated deferred investment tax credits	9,172	9,325
Regulatory liability for income taxes - net	137,959	144,145
Other regulatory liabilities	38,884	37,060
Asset retirement cost liabilities	8,638	8,520
Accumulated provisions	8,296	8,242
Long-term debt (includes securitization bonds of $24,953 as of March 31, 2022 and $53,979 as of December 31, 2021)	2,325,371	2,354,148
Other	67,777	67,760
TOTAL	3,291,247	3,321,696
Commitments and Contingencies
EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2022 and 2021	49,452	49,452
Paid-in capital	1,050,125	1,050,125
Retained earnings	1,394,764	1,344,879
Total common shareholder's equity	2,494,341	2,444,456
Preferred stock without sinking fund	38,750	38,750
TOTAL	2,533,091	2,483,206
TOTAL LIABILITIES AND EQUITY	$6,305,567	$6,261,411
See Notes to Financial Statements.

137

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
		Common Equity
	Preferred Stock	Common Stock	Paid-in Capital	Retained Earnings	Total
	(In Thousands)
Balance at December 31, 2020	$35,000	$49,452	$955,162	$1,117,964	$2,157,578
Net income	—	—	—	50,058	50,058
Preferred stock dividends	—	—	—	(470)	(470)
Balance at March 31, 2021	$35,000	$49,452	$955,162	$1,167,552	$2,207,166
Balance at December 31, 2021	$38,750	$49,452	$1,050,125	$1,344,879	$2,483,206
Net income	—	—	—	50,403	50,403
Preferred stock dividends	—	—	—	(518)	(518)
Balance at March 31, 2022	$38,750	$49,452	$1,050,125	$1,394,764	$2,533,091
See Notes to Financial Statements.

138

SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

System Energy’s principal asset currently consists of an ownership interest and a leasehold interest in Grand Gulf.  The capacity and energy from its 90% interest is sold under the Unit Power Sales Agreement to its only four customers, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans.  System Energy’s operating revenues are derived from the allocation of the capacity, energy, and related costs associated with its 90% interest in Grand Gulf pursuant to the Unit Power Sales Agreement.  Payments under the Unit Power Sales Agreement are System Energy’s only source of operating revenues. As discussed in “Complaints Against System Energy” below, System Energy is currently involved in proceedings at the FERC commenced by the retail regulators of its customers regarding its return on equity, its capital structure, its renewal of the sale-leaseback of 11.5% of Grand Gulf, the treatment of uncertain tax positions in rate base, the prudence of its operation of Grand Gulf, and the rates it charges under the Unit Power Sales Agreement.

Results of Operations

Net Income

Net income increased $7.6 million primarily due to the increase in operating revenues resulting from changes in rate base.

Income Taxes

The effective income tax rate was 23.2% for the first quarter 2022. The difference in the effective income tax rate for the first quarter 2022 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by book and tax differences related to the allowance for equity funds used during construction.

The effective income tax rate was (79.5%) for the first quarter 2021. The difference in the effective income tax rate for the first quarter 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, the amortization of investment tax credits, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

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Management's Financial Discussion and Analysis

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Cash and cash equivalents at beginning of period	$89,201	$242,469
Net cash provided by (used in):
Operating activities	40,011	(29,242)
Investing activities	(94,802)	(23,437)
Financing activities	63,845	(57,563)
Net increase (decrease) in cash and cash equivalents	9,054	(110,242)
Cash and cash equivalents at end of period	$98,255	$132,227

Operating Activities

System Energy’s operating activities provided $40 million of cash for the three months ended March 31, 2022 compared to using $29.2 million of cash for the three months ended March 31, 2021 primarily due to income tax payments of $39.1 million in 2021 and timing of payments to vendors, partially offset by an increase in spending of $12.7 million on nuclear refueling outages in 2022 as compared to the same period in 2021 and timing of collections of receivables. System Energy had income tax payments in 2021 as a result of the amended Mississippi tax returns filed based on federal adjustments related to the resolution of the 2014-2015 IRS audit, as well as a portion of the payments made in accordance with an intercompany income tax allocation agreement. See Note 3 to the financial statements in the Form 10-K for discussion of the 2014-2015 IRS audit.

Investing Activities

Net cash flow used in investing activities increased $71.4 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021 primarily due to:

•an increase of $71.9 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle; and

•an increase of $31.3 million in nuclear construction expenditures due to increased spending on various nuclear projects in 2022.

The increase was offset by money pool activity.

Decreases in System Energy’s receivable from the money pool are a source of cash flow and System Energy’s receivable from the money pool decreased by $18.6 million for the three months ended March 31, 2022 compared to increasing by $12.7 million for the three months ended March 31, 2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

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System Energy Resources, Inc.

Management's Financial Discussion and Analysis

Financing Activities

System Energy’s financing activities provided $63.8 million of cash for the three months ended March 31, 2022 compared to using $57.6 million of cash for the three months ended March 31, 2021 primarily due to:

•the repayment in February 2021 of $100 million of 3.42% Series J notes by the System Energy nuclear fuel company variable interest entity; and

•a decrease of $21 million in common stock dividends and distributions. No common stock dividends or distributions were made in 2022 in order to maintain System Energy’s capital structure.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to the net repayment of long-term debt in 2021.

	March 31, 2022		December 31, 2021
Debt to capital	41.8	%	40.4	%
Effect of subtracting cash	(3.2	%)	(3.0	%)
Net debt to net capital	38.6	%	37.4	%

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings and long-term debt, including the currently maturing portion.  Capital consists of debt and common equity.  Net capital consists of capital less cash and cash equivalents.  System Energy uses the debt to capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy’s financial condition.  System Energy uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy’s financial condition because net debt indicates System Energy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of System Energy’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

System Energy’s receivables from the money pool were as follows:

March 31, 2022	December 31, 2021	March 31, 2021	December 31, 2020
(In Thousands)
$57,139	$75,745	$16,682	$4,004

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $120 million scheduled to expire in June 2024. As of March 31, 2022, $100 million in loans were outstanding under the

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System Energy nuclear fuel company variable interest entity credit facility. See Note 4 to the financial statements herein for additional discussion of the variable interest entity credit facility.

Federal Regulation

See the “Rate, Cost-recovery, and Other Regulation - Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and Note 2 to the financial statements herein and in the Form 10-K for a discussion of federal regulation.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $45 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the

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Management's Financial Discussion and Analysis

leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of

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its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

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Management's Financial Discussion and Analysis

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in System Energy’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING REVENUES
Electric	$141,376	$117,746
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	7,923	16,859
Nuclear refueling outage expenses	5,927	6,718
Other operation and maintenance	43,904	41,960
Decommissioning	9,917	9,529
Taxes other than income taxes	7,851	6,825
Depreciation and amortization	29,923	28,194
Other regulatory charges (credits) - net	(8,524)	11,550
TOTAL	96,921	121,635
OPERATING INCOME (LOSS)	44,455	(3,889)
OTHER INCOME
Allowance for equity funds used during construction	2,047	1,111
Interest and investment income	5,232	27,442
Miscellaneous - net	(1,639)	(2,024)
TOTAL	5,640	26,529
INTEREST EXPENSE
Interest expense	9,481	9,535
Allowance for borrowed funds used during construction	(327)	(188)
TOTAL	9,154	9,347
INCOME BEFORE INCOME TAXES	40,941	13,293
Income taxes	9,509	(10,571)
NET INCOME	$31,432	$23,864
See Notes to Financial Statements.

146

SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	2022	2021
	(In Thousands)
OPERATING ACTIVITIES
Net income	$31,432	$23,864
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	46,566	53,433
Deferred income taxes, investment tax credits, and non-current taxes accrued	(8,690)	(10,197)
Changes in assets and liabilities:
Receivables	(3,845)	9,255
Accounts payable	(15,017)	(21,296)
Taxes accrued	5,939	(33,364)
Interest accrued	(475)	(1,088)
Other working capital accounts	(20,646)	2,347
Other regulatory assets	(2,331)	20,923
Other regulatory liabilities	(85,655)	(12,591)
Pension and other postretirement liabilities	(4,542)	(7,424)
Other assets and liabilities	97,275	(53,104)
Net cash flow provided by (used in) operating activities	40,011	(29,242)
INVESTING ACTIVITIES
Construction expenditures	(46,509)	(14,890)
Allowance for equity funds used during construction	2,047	1,111
Nuclear fuel purchases	(75,251)	(4,745)
Proceeds from the sale of nuclear fuel	11,257	12,626
Proceeds from nuclear decommissioning trust fund sales	62,717	211,481
Investment in nuclear decommissioning trust funds	(67,669)	(216,342)
Changes in money pool receivable - net	18,606	(12,678)
Net cash flow used in investing activities	(94,802)	(23,437)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	225,956	189,244
Retirement of long-term debt	(162,111)	(225,807)
Common stock dividends and distributions paid	—	(21,000)
Net cash flow provided by (used in) financing activities	63,845	(57,563)
Net increase (decrease) in cash and cash equivalents	9,054	(110,242)
Cash and cash equivalents at beginning of period	89,201	242,469
Cash and cash equivalents at end of period	$98,255	$132,227
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$9,749	$10,720
Income taxes	$—	$39,085
See Notes to Financial Statements.

147

SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$72	$87
Temporary cash investments	98,183	89,114
Total cash and cash equivalents	98,255	89,201
Accounts receivable:
Associated companies	102,258	118,977
Other	8,961	7,003
Total accounts receivable	111,219	125,980
Materials and supplies - at average cost	124,639	127,093
Deferred nuclear refueling outage costs	32,250	10,123
Prepayments and other	2,843	1,870
TOTAL	369,206	354,267
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,308,172	1,385,254
TOTAL	1,308,172	1,385,254
UTILITY PLANT
Electric	5,357,646	5,362,494
Construction work in progress	149,025	97,968
Nuclear fuel	210,446	171,438
TOTAL UTILITY PLANT	5,717,117	5,631,900
Less - accumulated depreciation and amortization	3,414,249	3,396,136
UTILITY PLANT - NET	2,302,868	2,235,764
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	397,877	395,546
Other	1,728	1,793
TOTAL	399,605	397,339
TOTAL ASSETS	$4,379,851	$4,372,624
See Notes to Financial Statements.

148

SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2022 and December 31, 2021
(Unaudited)
	2022	2021
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$50,335	$50,329
Accounts payable:
Associated companies	11,736	23,682
Other	70,571	62,573
Taxes accrued	38,857	32,918
Interest accrued	11,239	11,714
Other	4,101	4,101
TOTAL	186,839	185,317
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	373,447	382,931
Accumulated deferred investment tax credits	42,684	43,003
Regulatory liability for income taxes - net	111,511	113,165
Other regulatory liabilities	660,943	744,944
Decommissioning	1,017,520	1,007,603
Pension and other postretirement liabilities	71,562	76,104
Long-term debt	755,018	690,967
Other	37,535	37,230
TOTAL	3,070,220	3,095,947
Commitments and Contingencies
COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2022 and 2021	951,850	951,850
Retained earnings	170,942	139,510
TOTAL	1,122,792	1,091,360
TOTAL LIABILITIES AND EQUITY	$4,379,851	$4,372,624
See Notes to Financial Statements.

149

SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Three Months Ended March 31, 2022 and 2021
(Unaudited)
	Common Equity
	Common Stock	Retained Earnings	Total
	(In Thousands)
Balance at December 31, 2020	$951,850	$128,696	$1,080,546
Net income	—	23,864	23,864
Common stock dividends and distributions	—	(21,000)	(21,000)
Balance at March 31, 2021	$951,850	$131,560	$1,083,410
Balance at December 31, 2021	$951,850	$139,510	$1,091,360
Net income	—	31,432	31,432
Balance at March 31, 2022	$951,850	$170,942	$1,122,792
See Notes to Financial Statements.

150

ENTERGY CORPORATION AND SUBSIDIARIES

PART II. OTHER INFORMATION

Item 1.  Legal Proceedings

See “PART I, Item 1, Litigation” in the Form 10-K for a discussion of legal, administrative, and other regulatory proceedings affecting Entergy.  Also see Notes 1 and 2 to the financial statements herein and “Item 5, Other Information, Environmental Regulation” below for updates regarding environmental proceedings and regulation.

Item 1A.  Risk Factors

See the risk factors discussed in "Part I, Item 1A. RISK FACTORS" in the Form 10-K, which could materially affect Entergy's and its Registrant Subsidiaries' business, financial condition, or future results. The information set forth in this report, including the risk factor presented below, updates and should be read in conjunction with the risk factors and information disclosed in the Form 10-K.

The completion of capital projects, including the construction of power generation facilities, and other capital improvements involve substantial risks. Should such efforts be unsuccessful, the financial condition, results of operations, or liquidity of Entergy and the Utility operating companies could be materially affected.

Entergy’s and the Utility operating companies’ ability to complete capital projects, including the construction of power generation facilities, or make other capital improvements, in a timely manner and within budget is contingent upon many variables and subject to substantial risks. These variables include, but are not limited to, project management expertise, escalating costs for materials, labor, and environmental compliance, reliance on suppliers for timely and satisfactory performance, and pandemic-related delays and cost increases. Delays in obtaining permits, shortages in materials and qualified labor, levels of public support or opposition, suppliers and contractors not performing as expected or required under their contracts and/or experiencing financial problems that inhibit their ability to fulfill their obligations under contracts, changes in the scope and timing of projects, poor quality initial cost estimates from contractors, the inability to raise capital on favorable terms, changes in commodity prices affecting revenue, fuel costs, or materials costs, downward changes in the economy, changes in law or regulation, including environmental compliance requirements, trade and tariff issues associated with imported solar panels, supply chain delays or disruptions, and other events beyond the control of the Utility operating companies or the Entergy Wholesale Commodities business may occur that may materially affect the schedule, cost, and performance of these projects. If these projects or other capital improvements are significantly delayed or become subject to cost overruns or cancellation, Entergy and the Utility operating companies could incur additional costs and termination payments, or face increased risk of potential write-off of the investment in the project. In addition, the Utility operating companies could be exposed to higher costs and market volatility, which could affect cash flow and cost recovery, should their respective regulators decline to approve the construction of the project or new generation needed to meet the reliability needs of customers at the lowest reasonable cost.

For further information regarding capital expenditure plans and other uses of capital in connection with capital projects, including the potential construction and/or purchase of additional generation supply sources within the Utility operating companies’ service territory, see the “Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital” section of Management’s Financial Discussion and Analysis for Entergy herein and in the Form 10-K and the “Liquidity and Capital Resources - Uses of Capital” section of Management’s Financial Discussion and Analysis in the Form 10-K and the “Liquidity and Capital Resources - Uses and Sources of Capital” section of Management’s Financial Discussion and Analysis herein for each of the Registrant Subsidiaries.

151

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities (a)

Period	Total Number of Shares Purchased	Average Price Paid per Share	Total Number of Shares Purchased as Part of a Publicly Announced Plan	Maximum $ Amount of Shares that May Yet be Purchased Under a Plan (b)
1/01/2022-1/31/2022	—	$—	—	$350,052,918
2/01/2022-2/28/2022	—	$—	—	$350,052,918
3/01/2022-3/31/2022	—	$—	—	$350,052,918
Total	—	$—	—

In accordance with Entergy’s stock-based compensation plans, Entergy periodically grants stock options to key employees, which may be exercised to obtain shares of Entergy’s common stock.  According to the plans, these shares can be newly issued shares, treasury stock, or shares purchased on the open market.  Entergy’s management has been authorized by the Board to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plans.  In addition to this authority, the Board has authorized share repurchase programs to enable opportunistic purchases in response to market conditions. In October 2010 the Board granted authority for a $500 million share repurchase program. The amount of share repurchases under these programs may vary as a result of material changes in business results or capital spending or new investment opportunities.  In addition, in the first quarter 2022, Entergy withheld 79,738 shares of its common stock at $110.35 per share, 77,207 shares of its common stock at $111.16 per share, 35,940 shares of its common stock at $111.77 per share, 1,219 shares of its common stock at $109.01 per share, 577 shares of its common stock at $106.62 per share, 232 shares of its common stock at $110.77 per share, 87 shares of its common stock at $109.01 per share, and 82 shares of its common stock at $111.47 per share to pay income taxes due upon vesting of restricted stock granted and payout of performance units as part of its long-term incentive program.

(a)See Note 12 to the financial statements in the Form 10-K for additional discussion of the stock-based compensation plans.

(b)Maximum amount of shares that may yet be repurchased relates only to the $500 million plan and does not include an estimate of the amount of shares that may be purchased to fund the exercise of grants under the stock-based compensation plans.

Item 5.  Other Information

Regulation of the Nuclear Power Industry

Following is an update to the “Regulation of the Nuclear Power Industry” section of Part I, Item 1 of the Form 10-K.

Nuclear Waste Policy Act of 1982

Nuclear Plant Decommissioning

In March 2022 filings with the NRC were made reporting on decommissioning funding for Palisades and the Big Rock Point dry fuel storage facility. Those reports showed that decommissioning funding for those facilities met the NRC’s financial assurance requirements.

152

Environmental Regulation

Following are updates to the “Environmental Regulation” section of Part I, Item 1 of the Form 10-K.

National Ambient Air Quality Standards

See the Form 10-K for discussion of the National Ambient Air Quality Standards (NAAQS) set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.

Hazardous Air Pollutants

The EPA released the final Mercury and Air Toxics Standard (MATS) rule in December 2011, which had a compliance date, with a widely granted one-year extension, of April 2016. The required controls have been installed and are operational at all affected Entergy units. In May 2020 the EPA finalized a rule that finds that it is not “appropriate and necessary” to regulate hazardous air pollutants from electric steam generating units under the provisions of section 112(n) of the Clean Air Act. This is a reversal of the EPA’s previous finding requiring such regulation. The final appropriate and necessary finding does not revise the underlying MATS rule. Several lawsuits have been filed challenging the appropriate and necessary finding. In February 2021 the D.C. Circuit granted the EPA’s motion to hold the litigation in abeyance pending the agency’s review of the appropriate and necessary rule. In February 2022 the EPA issued a proposed rule revoking the 2020 rule and determining, again, that it is “appropriate and necessary” to regulate hazardous air pollutants. The EPA is seeking additional information, which it could use to further tighten the standard. Entergy will continue to monitor this situation.

Cross-State Air Pollution

As discussed in the Form 10-K, the Cross-State Air Pollution Rule (CSAPR) has been remanded to and modified by the EPA on multiple occasions. In April 2022 the EPA published a rule to address interstate transport for the 2015 ozone NAAQS and which will increase the stringency of the CSAPR program in all four of the states where the Utility operating companies operate. If finalized as proposed, the rule will significantly reduce emission allowances and would likely require the installation of post-combustion nitrogen oxides (NOx) emissions controls on any coal or large legacy gas units that will operate beyond 2026 and are not currently equipped with such controls, including certain of Entergy’s plants. Additionally the EPA is proposing controls on certain non-electric generating NOx sources. Since releasing the proposed rule, the price for Group 3 allowances has increased to $8,500 per allowance. Comments on the proposed rule are due in June 2022, and Entergy is currently evaluating the publication.

Regional Haze

As discussed in the Form 10-K, the second planning period (2018-2028) for the regional haze program required states to examine sources for impacts on visibility and to prepare State Implementation Plans (SIPs) by July 31, 2021 which the Arkansas Department of Energy and Environment, Division of Environmental Quality (ADEQ) did not meet. The ADEQ released a draft proposed SIP in February 2022. The ADEQ reviewed Entergy’s Independence plant, but determined that additional air emission controls would not be cost-effective considering the facility’s commitment to cease coal-fired combustion by December 31, 2030. The ADEQ is expected to finalize this SIP and submit to the EPA for review by the end of 2022.

The Texas Commission on Environmental Quality has completed its second-planning period SIP and submitted it to the EPA for review. There were no Entergy sources selected for additional emission controls. The Mississippi Department of Environmental Quality continues to develop its SIP, but there are no Entergy sources that are expected to be impacted.

153

Item 6.  Exhibits

4(a) -	Credit Agreement dated as of April 14, 2022, among Entergy Mississippi, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, and Citibank, N.A., as Administrative Agent (4.1 to Form 8-K filed April 14, 2022 in 1-31508).
*31(a) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
*31(b) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
*31(c) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
*31(d) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
*31(e) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
*31(f) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
*31(g) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
*31(h) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
*31(i) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
*31(j) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
*31(k) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
*31(l) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
*31(m) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.
*31(n) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.
**32(a) -	Section 1350 Certification for Entergy Corporation.
**32(b) -	Section 1350 Certification for Entergy Corporation.
**32(c) -	Section 1350 Certification for Entergy Arkansas.
**32(d) -	Section 1350 Certification for Entergy Arkansas.
**32(e) -	Section 1350 Certification for Entergy Louisiana.
**32(f) -	Section 1350 Certification for Entergy Louisiana.
**32(g) -	Section 1350 Certification for Entergy Mississippi.
**32(h) -	Section 1350 Certification for Entergy Mississippi.
**32(i) -	Section 1350 Certification for Entergy New Orleans.
**32(j) -	Section 1350 Certification for Entergy New Orleans.
**32(k) -	Section 1350 Certification for Entergy Texas.
**32(l) -	Section 1350 Certification for Entergy Texas.
**32(m) -	Section 1350 Certification for System Energy.
**32(n) -	Section 1350 Certification for System Energy.
*101 INS -	Inline XBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
*101 SCH -	Inline XBRL Schema Document.
*101 PRE -	Inline XBRL Presentation Linkbase Document.
*101 LAB -	Inline XBRL Label Linkbase Document.
*101 CAL -	Inline XBRL Calculation Linkbase Document.
*101 DEF -	Inline XBRL Definition Linkbase Document.

154

*104 - Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibits 101).

___________________________

Pursuant to Item 601(b)(4)(iii) of Regulation S-K, Entergy Corporation agrees to furnish to the Commission upon request any instrument with respect to long-term debt that is not registered or listed herein as an Exhibit because the total amount of securities authorized under such agreement does not exceed ten percent of the total assets of Entergy Corporation and its subsidiaries on a consolidated basis.

*	Filed herewith.
**	Furnished, not filed, herewith.

155

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.  The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

ENTERGY CORPORATION
ENTERGY ARKANSAS, LLC
ENTERGY LOUISIANA, LLC
ENTERGY MISSISSIPPI, LLC
ENTERGY NEW ORLEANS, LLC
ENTERGY TEXAS, INC.
SYSTEM ENERGY RESOURCES, INC.

/s/ Kimberly A. Fontan

Kimberly A. Fontan
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)

Date:    May 5, 2022

156

EX-31.A

Exhibit 31(a)

CERTIFICATIONS

I, Leo P. Denault, certify that:

I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;

1.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

2.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

3.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

4.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Leo P. Denault

Leo P. Denault

Chairman of the Board and Chief Executive Officer

of Entergy Corporation

Date:  May 5, 2022

EX-31.B

Exhibit 31(b)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;

1.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

2.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

3.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

4.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Corporation

Date:  May 5, 2022

EX-31.C

Exhibit 31(c)

CERTIFICATIONS

I, Laura R. Landreaux, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Laura R. Landreaux

Laura R. Landreaux

Chair of the Board, President, and

Chief Executive Officer of Entergy Arkansas, LLC

Date:  May 5, 2022

EX-31.D

Exhibit 31(d)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Arkansas, LLC

Date:  May 5, 2022

EX-31.E

Exhibit 31(e)

CERTIFICATIONS

I, Phillip R. May, Jr., certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Phillip R. May, Jr.

Phillip R. May, Jr.

Chairman of the Board, President, and Chief Executive

Officer of Entergy Louisiana, LLC

Date:  May 5, 2022

EX-31.F

Exhibit 31(f)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Louisiana, LLC

Date:  May 5, 2022

EX-31.G

Exhibit 31(g)

CERTIFICATIONS

I, Haley R. Fisackerly, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Haley R. Fisackerly

Haley R. Fisackerly

Chairman of the Board, President, and Chief Executive Officer

of Entergy Mississippi, LLC

Date:  May 5, 2022

EX-31.H

Exhibit 31(h)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Mississippi, LLC

Date:  May 5, 2022

EX-31.I

Exhibit 31(i)

CERTIFICATIONS

I, Deanna D. Rodriguez, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Deanna D. Rodriguez

Deanna D. Rodriguez

Chair of the Board, President, and Chief Executive Officer

of Entergy New Orleans, LLC

Date:  May 5, 2022

EX-31.J

Exhibit 31(j)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy New Orleans, LLC

Date:  May 5, 2022

EX-31.K

Exhibit 31(k)

CERTIFICATIONS

I, Eliecer Viamontes, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Texas, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Eliecer Viamontes

Eliecer Viamontes

Chairman of the Board, President, and Chief Executive Officer

of Entergy Texas, Inc.

Date:  May 5, 2022

EX-31.L

Exhibit 31(l)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Entergy Texas, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Texas, Inc.

Date:  May 5, 2022

EX-31.M

Exhibit 31(m)

CERTIFICATIONS

I, Roderick K. West, certify that:

1.I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Roderick K. West

Roderick K. West

Chairman of the Board, President, and Chief Executive Officer

of System Energy Resources, Inc.

Date:  May 5, 2022

EX-31.N

Exhibit 31(n)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of System Energy Resources, Inc.

Date:  May 5, 2022

EX-32.A

Exhibit 32(a)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Leo P. Denault, Chairman of the Board and Chief Executive Officer of Entergy Corporation (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Leo P. Denault

     Leo P. Denault

Chairman of the Board and Chief Executive Officer

of Entergy Corporation

Date: May 5, 2022

EX-32.B

Exhibit 32(b)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Corporation (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh

     Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Corporation

Date: May 5, 2022

EX-32.C

Exhibit 32(c)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Laura R. Landreaux, Chair of the Board, President, and Chief Executive Officer of Entergy Arkansas, LLC (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Laura R. Landreaux

Laura R. Landreaux

Chair of the Board, President, and Chief Executive

Officer of Entergy Arkansas, LLC

Date: May 5, 2022

EX-32.D

Exhibit 32(d)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Arkansas, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh

     Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Arkansas, LLC

Date: May 5, 2022

EX-32.E

Exhibit 32(e)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Phillip R. May, Jr., Chairman of the Board, President, and Chief Executive Officer of Entergy Louisiana, LLC (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Phillip R. May, Jr.

     Phillip R. May, Jr.

Chairman of the Board, President, and Chief Executive

Officer of Entergy Louisiana, LLC

Date: May 5, 2022

EX-32.F

Exhibit 32(f)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Louisiana, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh

     Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Louisiana, LLC

Date: May 5, 2022

EX-32.G

Exhibit 32(g)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Haley R. Fisackerly, Chairman of the Board, President, and Chief Executive Officer of Entergy Mississippi, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Haley R. Fisackerly

Haley R. Fisackerly

Chairman of the Board, President, and Chief Executive

Officer of Entergy Mississippi, LLC

Date: May 5, 2022

EX-32.H

Exhibit 32(h)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Mississippi, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Mississippi, LLC

Date: May 5, 2022

EX-32.I

Exhibit 32(i)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Deanna D. Rodriguez, Chair of the Board, President, and Chief Executive Officer of Entergy New Orleans, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Deanna D. Rodriguez

Deanna D. Rodriguez

Chair of the Board, President, and Chief Executive

Officer of Entergy New Orleans, LLC

Date: May 5, 2022

EX-32.J

Exhibit 32(j)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy New Orleans, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy New Orleans, LLC

Date: May 5, 2022

EX-32.K

Exhibit 32(k)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Eliecer Viamontes, Chairman of the Board, President, and Chief Executive Officer of Entergy Texas, Inc. (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Eliecer Viamontes

Eliecer Viamontes

Chairman of the Board, President, and Chief Executive Officer

of Entergy Texas, Inc.

Date: May 5, 2022

EX-32.L

Exhibit 32(l)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Texas, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial Officer

of Entergy Texas, Inc.

Date: May 5, 2022

EX-32.M

Exhibit 32(m)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Roderick K. West, Chairman of the Board, President, and Chief Executive Officer of System Energy Resources, Inc. (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Roderick K. West

Roderick K. West

Chairman of the Board, President, and Chief Executive Officer

of System Energy Resources, Inc.

Date: May 5, 2022

EX-32.N

Exhibit 32(n)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of System Energy Resources, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2022 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh

Andrew S. Marsh

Executive Vice President and Chief Financial

Officer of System Energy Resources, Inc.

Date: May 5, 2022

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2022	Apr. 29, 2022
Entity Registrant Name	ENTERGY CORPORATION
City Area Code	504
Local Phone Number	576-4000
Entity Tax Identification Number	72-1229752
Entity File Number	1-11299
Entity Central Index Key	0000065984
Document Type	10-Q
Document Period End Date	Mar. 31, 2022
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Incorporation, State or Country Code	DE
Entity Address, State or Province	639 Loyola Avenue
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70113
Entity Common Stock, Shares Outstanding		203,374,308
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Document Quarterly Report	true
Document Transition Report	false
NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ETR
Security Exchange Name	NYSE
Title of 12(b) Security	Common Stock, $0.01 Par Value
CHICAGO STOCK EXCHANGE, INC [Member]
Trading Symbol	ETR
Security Exchange Name	CHX
Title of 12(b) Security	Common Stock, $0.01 Par Value
Entergy Arkansas [Member]
Entity Registrant Name	ENTERGY ARKANSAS, LLC
City Area Code	501
Local Phone Number	377-4000
Entity Tax Identification Number	83-1918668
Entity File Number	1-10764
Entity Central Index Key	0000007323
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	425 West Capitol Avenue
Entity Address, City or Town	Little Rock
Entity Address, State or Province	AR
Entity Address, Postal Zip Code	72201
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Louisiana [Member]
Entity Registrant Name	ENTERGY LOUISIANA, LLC
City Area Code	504
Local Phone Number	576-4000
Entity Tax Identification Number	47-4469646
Entity File Number	1-32718
Entity Central Index Key	0001348952
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	4809 Jefferson Highway
Entity Address, City or Town	Jefferson
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70121
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Mississippi [Member]
Entity Registrant Name	ENTERGY MISSISSIPPI, LLC
City Area Code	601
Local Phone Number	368-5000
Entity Tax Identification Number	83-1950019
Entity File Number	1-31508
Entity Central Index Key	0000066901
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	308 East Pearl Street
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39201
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy New Orleans [Member]
Entity Registrant Name	ENTERGY NEW ORLEANS, LLC
City Area Code	504
Local Phone Number	670-3700
Entity Tax Identification Number	82-2212934
Entity File Number	1-35747
Entity Central Index Key	0000071508
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	1600 Perdido Street
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70112
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Texas [Member]
Entity Registrant Name	ENTERGY TEXAS, INC.
City Area Code	409
Local Phone Number	981-2000
Entity Tax Identification Number	61-1435798
Entity File Number	1-34360
Entity Central Index Key	0001427437
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	2107 Research Forest Drive
Entity Address, City or Town	The Woodlands
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77380
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
System Energy [Member]
Entity Registrant Name	SYSTEM ENERGY RESOURCES, INC.
City Area Code	601
Local Phone Number	368-5000
Entity Tax Identification Number	72-0752777
Entity File Number	1-09067
Entity Central Index Key	0000202584
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	AR
Entity Address, State or Province	1340 Echelon Parkway
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39213
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Mortgage Bonds, Five Point Five Percent Series, Due April Two Thousand Sixty Six [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ENO
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.50% Series due April 2066
Mortgage Bonds 5.0 Series Due December Two Thousand Fifty Two [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ENJ
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.0% Series due December 2052
Mortgage Bonds, Four Point Nine Zero Percent Series, Due October Two Thousand Sixty Six [Member] | Entergy Mississippi [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EMP
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.90% Series due October 2066
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EAI
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ELC
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
5.375% Series A Preferred Stock, Cumulative, No Par Value [Domain] | Entergy Texas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ETI/PR
Security Exchange Name	NYSE
Title of 12(b) Security	5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)

XML

Consolidated Statements Of Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,877,925	$ 2,844,838
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	666,938	501,167
Nuclear refueling outage expenses	43,002	43,739
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	678,812	706,786
Asset Impairment Charges	744	3,273
Decommissioning	62,048	98,642
Taxes, Other	180,148	156,702
Other Depreciation and Amortization	438,972	414,519
Other regulatory charges (credits) - net	(28,425)	32,279
Costs and Expenses	2,311,865	2,336,841
OPERATING INCOME	566,060	507,997
OTHER INCOME
Allowance for equity funds used during construction	15,871	14,577
Investment Income, Net	(21,918)	143,315
Miscellaneous - net	7,603	(60,929)
TOTAL	1,556	96,963
INTEREST EXPENSE
Interest Expense, Debt	227,622	205,886
Allowance for borrowed funds used during construction	(6,096)	(6,013)
TOTAL	221,526	199,873
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	346,090	405,087
Income taxes	66,497	65,942
Consolidated net income	279,593	339,145
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	$ 3,193	$ 4,580
Earnings per average common share:
Basic (in dollars per share)	$ 1.36	$ 1.67
Diluted (in dollars per share)	$ 1.36	$ 1.66
Basic average number of common shares outstanding (in shares)	202,943,628	200,525,549
Diluted average number of common shares outstanding (in shares)	203,888,483	201,059,665
Net Income (Loss) Available to Common Stockholders, Basic	$ 276,400	$ 334,565
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	2,655,776	2,538,420
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	72,361	58,168
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	149,788	248,250
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	269,626	379,734
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	349,029	336,619
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	67,277	60,197
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	65,811	67,831
Taxes, Other	32,730	25,899
Other Depreciation and Amortization	60,084	55,036
Other regulatory charges (credits) - net	3,907	8,129
Costs and Expenses	291,021	285,683
OPERATING INCOME	58,008	50,936
OTHER INCOME
Allowance for equity funds used during construction	1,078	1,668
Investment Income, Net	64	42
Miscellaneous - net	(1,153)	(2,313)
TOTAL	(11)	(603)
INTEREST EXPENSE
Interest Expense, Debt	20,434	17,613
Allowance for borrowed funds used during construction	(465)	(677)
TOTAL	19,969	16,936
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	38,028	33,397
Income taxes	7,673	7,425
Consolidated net income	30,355	25,972
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	349,029	336,619
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Entergy Mississippi [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	61,212	68,591
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	558,956	583,386
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	86,225	126,181
Nuclear refueling outage expenses	14,070	12,647
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	157,257	154,908
Decommissioning	20,129	19,000
Taxes, Other	33,202	29,743
Other Depreciation and Amortization	95,610	88,279
Other regulatory charges (credits) - net	(20,542)	(37,467)
Costs and Expenses	443,422	463,512
OPERATING INCOME	115,534	119,874
OTHER INCOME
Allowance for equity funds used during construction	3,055	2,993
Investment Income, Net	6,320	27,887
Miscellaneous - net	(5,392)	(5,791)
TOTAL	3,983	25,089
INTEREST EXPENSE
Interest Expense, Debt	36,047	33,786
Allowance for borrowed funds used during construction	(1,214)	(1,290)
TOTAL	34,833	32,496
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	84,684	112,467
Income taxes	19,117	19,430
Consolidated net income	65,567	93,037
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	(1,387)	0
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	66,954	93,037
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	558,956	583,386
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Entergy Arkansas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	57,471	70,221
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,265,972	1,107,644
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	362,074	145,234
Nuclear refueling outage expenses	11,947	13,282
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	254,001	237,483
Decommissioning	17,688	16,823
Taxes, Other	61,615	52,484
Other Depreciation and Amortization	169,083	160,813
Other regulatory charges (credits) - net	(20,897)	31,097
Costs and Expenses	1,031,708	867,177
OPERATING INCOME	234,264	240,467
OTHER INCOME
Allowance for equity funds used during construction	6,726	6,101
Investment Income, Net	15,900	72,515
Miscellaneous - net	15,517	(34,638)
TOTAL	38,143	43,978
INTEREST EXPENSE
Interest Expense, Debt	93,784	82,806
Allowance for borrowed funds used during construction	(3,026)	(2,759)
TOTAL	90,758	80,047
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	181,649	204,398
Income taxes	30,789	37,772
Consolidated net income	150,860	166,626
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	150,860	166,626
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,237,237	1,079,663
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	28,735	27,981
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	176,197	209,961
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	198,272	169,335
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	43,397	19,012
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	33,652	38,178
Taxes, Other	13,989	12,556
Other Depreciation and Amortization	19,815	18,161
Other regulatory charges (credits) - net	4,185	3,130
Costs and Expenses	171,508	159,707
OPERATING INCOME	26,764	9,628
OTHER INCOME
Allowance for equity funds used during construction	369	258
Investment Income, Net	24	9
Miscellaneous - net	(271)	(302)
TOTAL	122	(35)
INTEREST EXPENSE
Interest Expense, Debt	8,694	7,029
Allowance for borrowed funds used during construction	(199)	(116)
TOTAL	8,495	6,913
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	18,391	2,680
Income taxes	3,265	909
Consolidated net income	15,126	1,771
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	154,646	139,148
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	43,626	30,187
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	56,470	68,670
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	472,482	480,220
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	73,920	112,396
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	74,977	62,955
Taxes, Other	20,449	21,875
Other Depreciation and Amortization	56,061	50,936
Other regulatory charges (credits) - net	13,446	15,840
Costs and Expenses	399,943	405,364
OPERATING INCOME	72,539	74,856
OTHER INCOME
Allowance for equity funds used during construction	2,596	2,445
Investment Income, Net	188	224
Miscellaneous - net	307	(423)
TOTAL	3,091	2,246
INTEREST EXPENSE
Interest Expense, Debt	20,912	23,038
Allowance for borrowed funds used during construction	(865)	(984)
TOTAL	20,047	22,054
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	55,583	55,048
Income taxes	5,180	4,990
Consolidated net income	50,403	50,058
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	518	470
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	49,885	49,588
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	472,482	480,220
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Entergy Texas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	161,090	141,362
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	7,923	16,859
Nuclear refueling outage expenses	5,927	6,718
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	43,904	41,960
Decommissioning	9,917	9,529
Taxes, Other	7,851	6,825
Other Depreciation and Amortization	29,923	28,194
Other regulatory charges (credits) - net	(8,524)	11,550
Costs and Expenses	96,921	121,635
OPERATING INCOME	44,455	(3,889)
OTHER INCOME
Allowance for equity funds used during construction	2,047	1,111
Investment Income, Net	5,232	27,442
Miscellaneous - net	(1,639)	(2,024)
TOTAL	5,640	26,529
INTEREST EXPENSE
Interest Expense, Debt	9,481	9,535
Allowance for borrowed funds used during construction	(327)	(188)
TOTAL	9,154	9,347
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	40,941	13,293
Income taxes	9,509	(10,571)
Consolidated net income	31,432	23,864
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	31,432	23,864
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 141,376	$ 117,746

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Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
OPERATING ACTIVITIES
Consolidated net income	$ 279,593	$ 339,145
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	561,731	580,571
Deferred income taxes, investment tax credits, and non-current taxes accrued	70,780	240,431
Impairment of Long-Lived Assets Held-for-use	744	3,278
Changes in working capital:
Receivables	122,987	(52,690)
Fuel inventory	14,795	26,878
Accounts payable	(283,175)	(175,651)
Taxes accrued	(79,941)	(231,182)
Interest accrued	32,862	(3,778)
Deferred fuel costs	(58,932)	(353,099)
Other working capital accounts	(95,033)	(43,582)
Changes in provisions for estimated losses	8,206	(60,923)
Changes in other regulatory assets	(1,424,270)	89,910
Increase (Decrease) in Regulatory Liabilities	(250,358)	(14,464)
Storm restoration costs approved for securitization recognized as regulatory asset	1,491,942	0
Changes in pension and other postretirement liabilities	(101,641)	(166,733)
Other Noncash Income (Expense)	247,676	(227,676)
Net cash flow provided by (used in) operating activities	537,966	(49,565)
INVESTING ACTIVITIES
Construction/capital expenditures	(1,501,578)	(1,552,103)
Allowance for equity funds used during construction	15,871	14,577
Nuclear fuel purchases	(83,326)	(47,916)
Payments for Nuclear Fuel	(83,326)	(47,916)
Proceeds from insurance	9,829	0
Payments to storm reserve escrow account	0	(10)
Receipts from storm reserve escrow account	0	44,205
Decrease (increase) in other investments	(11,862)	12,521
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	32,367	15,735
Proceeds from nuclear decommissioning trust fund sales	479,937	3,225,510
Investment in nuclear decommissioning trust funds	(505,989)	(3,224,487)
Changes in securitization account	13,532	(1,304)
Net cash flow used in investing activities	(1,551,219)	(1,513,272)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	2,553,369	3,676,242
Proceeds from Sale of Treasury Stock	9,629	979
Retirement of long-term debt	(1,224,091)	(1,346,172)
Changes in credit borrowings and commercial paper - net	141,634	(599,860)
Dividends paid:
Common stock	(205,058)	(190,595)
Other	1,382	10,380
Net cash flow provided by financing activities	1,272,285	1,546,394
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	259,032	(16,443)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	701,591	1,742,656
Cash paid / (received) during the period for:
Interest - net of amount capitalized	186,269	202,451
Income taxes	(11,505)	9,015
Dividends Paid, Preferred Stock	(4,580)	(4,580)
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income	65,567	93,037
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	133,634	126,630
Deferred income taxes, investment tax credits, and non-current taxes accrued	11,776	42,885
Changes in working capital:
Receivables	23,583	(56,256)
Fuel inventory	7,199	17,930
Accounts payable	(33,409)	(21,622)
Taxes accrued	27,209	8,365
Interest accrued	32,233	18,837
Deferred fuel costs	(16,954)	(55,704)
Other working capital accounts	3,794	(8,025)
Changes in provisions for estimated losses	(309)	(12,383)
Changes in other regulatory assets	(7,198)	42,388
Increase (Decrease) in Regulatory Liabilities	(91,068)	(38,604)
Changes in pension and other postretirement liabilities	(19,852)	(25,116)
Other Noncash Income (Expense)	111,221	(40,789)
Net cash flow provided by (used in) operating activities	247,426	91,573
INVESTING ACTIVITIES
Construction/capital expenditures	(162,108)	(146,334)
Allowance for equity funds used during construction	3,055	2,993
Nuclear fuel purchases	(27,258)	(17,621)
Payments for Nuclear Fuel	(27,258)	(17,621)
Proceeds from sale of nuclear fuel	37,157	16,059
Change in money pool receivable - net	(59,981)	(12,500)
Proceeds from nuclear decommissioning trust fund sales	64,608	143,575
Investment in nuclear decommissioning trust funds	(69,950)	(148,783)
Net cash flow used in investing activities	(214,477)	(162,611)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	212,060	604,760
Retirement of long-term debt	(7,506)	(613,706)
Change in money pool payable - net	(139,904)	0
Dividends paid:
Other	(483)	11,636
Net cash flow provided by financing activities	64,167	2,690
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	97,116	(68,348)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	110,031	123,780
Cash paid / (received) during the period for:
Interest - net of amount capitalized	3,227	14,359
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income	150,860	166,626
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	213,022	198,868
Deferred income taxes, investment tax credits, and non-current taxes accrued	95,785	67,823
Changes in working capital:
Receivables	71,237	(13,080)
Fuel inventory	(46)	1,194
Accounts payable	(262,042)	(126,070)
Taxes accrued	(42,950)	20,619
Interest accrued	(857)	(9,163)
Deferred fuel costs	498	(203,815)
Other working capital accounts	(24,241)	(25,628)
Changes in provisions for estimated losses	2,694	(258)
Changes in other regulatory assets	(1,336,616)	(70,784)
Increase (Decrease) in Regulatory Liabilities	(67,164)	22,503
Storm restoration costs approved for securitization recognized as regulatory asset	1,338,559	0
Changes in pension and other postretirement liabilities	(11,608)	(30,745)
Other Noncash Income (Expense)	55,995	(52,688)
Net cash flow provided by (used in) operating activities	183,126	(54,598)
INVESTING ACTIVITIES
Construction/capital expenditures	(935,692)	(945,831)
Allowance for equity funds used during construction	6,726	6,101
Nuclear fuel purchases	(55,913)	(52,435)
Payments for Nuclear Fuel	(55,913)	(52,435)
Proceeds from sale of nuclear fuel	26,681	0
Change in money pool receivable - net	(66,621)	(62,346)
Proceeds from insurance	5,695	0
Decrease (increase) in other investments	17	0
Proceeds from nuclear decommissioning trust fund sales	155,269	291,275
Investment in nuclear decommissioning trust funds	(168,283)	(329,180)
Changes in securitization account	0	(6,050)
Net cash flow used in investing activities	(1,032,121)	(1,098,466)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	1,506,637	1,399,245
Retirement of long-term debt	(401,411)	(368,707)
Dividends paid:
Common stock	(125,000)	0
Other	6,843	(3,678)
Net cash flow provided by financing activities	987,069	1,026,860
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	138,074	(126,204)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	156,647	601,816
Cash paid / (received) during the period for:
Interest - net of amount capitalized	91,441	89,432
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income	30,355	25,972
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	60,084	55,036
Deferred income taxes, investment tax credits, and non-current taxes accrued	3,979	22,593
Changes in working capital:
Receivables	(6,379)	4,557
Fuel inventory	23	1,736
Accounts payable	989	26,391
Taxes accrued	(63,785)	(75,886)
Interest accrued	10,613	4,238
Deferred fuel costs	(24,076)	(25,722)
Other working capital accounts	(46,494)	(3,425)
Changes in provisions for estimated losses	(179)	(7,689)
Changes in other regulatory assets	16,301	11,015
Increase (Decrease) in Regulatory Liabilities	21,689	19,147
Changes in pension and other postretirement liabilities	(3,906)	(5,668)
Other Noncash Income (Expense)	(3,554)	2,016
Net cash flow provided by (used in) operating activities	(4,340)	54,311
INVESTING ACTIVITIES
Construction/capital expenditures	(102,686)	(154,788)
Allowance for equity funds used during construction	1,078	1,668
Change in money pool receivable - net	40,456	(9,683)
Decrease (increase) in other investments	(2)	1
Net cash flow used in investing activities	(61,154)	(162,802)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	0	200,573
Change in money pool payable - net	22,386	(16,516)
Dividends paid:
Other	(4,491)	1,132
Net cash flow provided by financing activities	17,895	185,189
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(47,599)	76,698
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	28	76,716
Cash paid / (received) during the period for:
Interest - net of amount capitalized	9,160	12,757
Income taxes	0	(8,045)
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income	15,126	1,771
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	19,815	18,161
Deferred income taxes, investment tax credits, and non-current taxes accrued	9,558	4,572
Changes in working capital:
Receivables	39,328	(1,975)
Fuel inventory	446	2,234
Accounts payable	(14,168)	(27,777)
Taxes accrued	(2,803)	13
Interest accrued	(613)	(3,203)
Deferred fuel costs	(9,959)	(4,886)
Other working capital accounts	(10,876)	(11,103)
Changes in provisions for estimated losses	6,224	(40,680)
Changes in other regulatory assets	25,499	28,879
Increase (Decrease) in Regulatory Liabilities	(16,667)	8,728
Changes in pension and other postretirement liabilities	(2,782)	(4,397)
Other Noncash Income (Expense)	(16,317)	15,549
Net cash flow provided by (used in) operating activities	41,811	(14,114)
INVESTING ACTIVITIES
Construction/capital expenditures	(68,959)	(26,165)
Allowance for equity funds used during construction	369	258
Change in money pool receivable - net	18,288	0
Payments to storm reserve escrow account	0	(3)
Receipts from storm reserve escrow account	0	44,200
Changes in securitization account	(3,099)	(3,415)
Net cash flow used in investing activities	(53,401)	14,875
Proceeds from the issuance of:
Change in money pool payable - net	0	15,039
Dividends paid:
Other	(107)	(214)
Net cash flow provided by financing activities	(107)	14,825
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(11,697)	15,586
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	31,165	15,612
Cash paid / (received) during the period for:
Interest - net of amount capitalized	8,957	9,921
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income	50,403	50,058
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	56,061	50,936
Deferred income taxes, investment tax credits, and non-current taxes accrued	(1,175)	(1,522)
Changes in working capital:
Receivables	(1,674)	(16,424)
Fuel inventory	8,039	3,509
Accounts payable	4,492	(42,511)
Taxes accrued	(15,188)	(5,123)
Interest accrued	(11,195)	(10,989)
Deferred fuel costs	(8,440)	(62,970)
Other working capital accounts	4,832	1,118
Changes in provisions for estimated losses	54	(31)
Changes in other regulatory assets	(135,079)	40,484
Increase (Decrease) in Regulatory Liabilities	(11,491)	(13,649)
Storm restoration costs approved for securitization recognized as regulatory asset	153,383	0
Changes in pension and other postretirement liabilities	(4,146)	(5,434)
Other Noncash Income (Expense)	(6,538)	(16,316)
Net cash flow provided by (used in) operating activities	82,338	(28,864)
INVESTING ACTIVITIES
Construction/capital expenditures	(155,948)	(238,903)
Allowance for equity funds used during construction	2,596	2,445
Change in money pool receivable - net	0	4,601
Proceeds from insurance	4,134	0
Decrease (increase) in other investments	(11,949)	0
Changes in securitization account	16,631	8,161
Net cash flow used in investing activities	(144,536)	(223,696)
Proceeds from the issuance of:
Retirement of long-term debt	(29,064)	(27,951)
Change in money pool payable - net	91,799	30,858
Dividends paid:
Other	(34)	1,552
Net cash flow provided by financing activities	62,196	3,989
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(2)	(248,571)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	26	25
Cash paid / (received) during the period for:
Interest - net of amount capitalized	31,513	33,394
Income taxes	(1,913)	(836)
Dividends Paid, Preferred Stock	(505)	(470)
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income	31,432	23,864
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	46,566	53,433
Deferred income taxes, investment tax credits, and non-current taxes accrued	(8,690)	(10,197)
Changes in working capital:
Receivables	(3,845)	9,255
Accounts payable	(15,017)	(21,296)
Taxes accrued	5,939	(33,364)
Interest accrued	(475)	(1,088)
Other working capital accounts	(20,646)	2,347
Changes in other regulatory assets	(2,331)	20,923
Increase (Decrease) in Regulatory Liabilities	(85,655)	(12,591)
Changes in pension and other postretirement liabilities	(4,542)	(7,424)
Other Noncash Income (Expense)	97,275	(53,104)
Net cash flow provided by (used in) operating activities	40,011	(29,242)
INVESTING ACTIVITIES
Construction/capital expenditures	(46,509)	(14,890)
Allowance for equity funds used during construction	2,047	1,111
Nuclear fuel purchases	(75,251)	(4,745)
Payments for Nuclear Fuel	(75,251)	(4,745)
Proceeds from sale of nuclear fuel	11,257	12,626
Change in money pool receivable - net	18,606	(12,678)
Proceeds from nuclear decommissioning trust fund sales	62,717	211,481
Investment in nuclear decommissioning trust funds	(67,669)	(216,342)
Net cash flow used in investing activities	(94,802)	(23,437)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	225,956	189,244
Retirement of long-term debt	(162,111)	(225,807)
Dividends paid:
Common stock	0	(21,000)
Net cash flow provided by financing activities	63,845	(57,563)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	9,054	(110,242)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	98,255	132,227
Cash paid / (received) during the period for:
Interest - net of amount capitalized	9,749	10,720
Income taxes	$ 0	$ 39,085

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Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Cash and cash equivalents:
Cash	$ 76,146	$ 44,944
Temporary cash investments	625,445	397,615
Total cash and cash equivalents	701,591	442,559
Accounts receivable:
Customer	668,620	786,866
Allowance for doubtful accounts	(31,486)	(68,608)
Other	171,858	231,843
Accrued unbilled revenues	406,010	420,255
Total accounts receivable	1,215,002	1,370,356
Deferred Fuel Cost	375,670	324,394
Fuel inventory - at average cost	139,780	154,575
Public Utilities, Inventory	1,066,535	1,041,515
Deferred nuclear refueling outage costs	125,192	133,422
Prepaid Expense and Other Assets, Current	215,231	156,774
TOTAL	3,839,001	3,623,595
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	5,210,130	5,514,016
Non-utility property - at cost (less accumulated depreciation)	357,092	357,576
Other	159,728	159,455
TOTAL	5,726,950	6,031,047
PROPERTY, PLANT, AND EQUIPMENT
Electric	63,405,911	64,263,250
Natural gas	666,646	658,989
Construction work in progress	1,556,651	1,511,966
Nuclear fuel	547,706	577,006
TOTAL PROPERTY, PLANT, AND EQUIPMENT	66,176,914	67,011,211
Less - accumulated depreciation and amortization	24,982,767	24,767,051
PROPERTY, PLANT, AND EQUIPMENT - NET	41,194,147	42,244,160
Regulatory assets:
Other regulatory assets	8,037,526	6,613,256
Deferred Fuel Cost Non Current	241,002	240,953
Goodwill	377,172	377,172
Deferred Income Tax Assets, Net	58,388	54,186
Other	359,340	269,873
Deferred Costs and Other Assets	9,073,428	7,555,440
TOTAL ASSETS	59,833,526	59,454,242
CURRENT LIABILITIES
Currently maturing long-term debt	1,039,335	1,039,329
Short-term borrowings	1,342,811	1,201,177
Accounts payable	1,741,052	2,610,132
Contract with Customer, Liability, Current	402,600	395,184
Taxes Payable, Current	339,887	419,828
Interest accrued	224,013	191,151
Deferred fuel costs	0	7,607
Pension and other postretirement liabilities	60,249	68,336
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	35,241	53,385
Other	177,997	204,613
TOTAL	5,363,185	6,190,742
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,796,208	4,706,797
Accumulated deferred investment tax credits	209,921	211,975
Regulatory liability for income taxes - net	1,233,417	1,255,692
Other regulatory liabilities	2,433,906	2,643,845
Decommissioning and asset retirement cost liabilities	4,816,524	4,757,084
Loss Contingency Accrual	165,328	157,122
Pension and other postretirement liabilities	1,855,771	1,949,325
Long-term debt	26,176,449	24,841,572
Deferred Credits and Other Liabilities	786,581	815,284
TOTAL	42,474,105	41,338,696
Subsidiaries' preferred stock without sinking fund	219,410	219,410
Proceeds from Issuance of Preferred Stock and Preference Stock	0	0
Common Shareholders' Equity:
Common Stock, Value, Issued	2,720	2,720
Additional Paid in Capital, Common Stock	6,735,154	6,766,239
Accumulated other comprehensive loss	(336,578)	(332,528)
Less - treasury stock, at cost	5,003,087	5,039,699
TOTAL	11,710,103	11,637,284
Stockholders' Equity Attributable to Noncontrolling Interest	66,723	68,110
Retained Earnings (Accumulated Deficit)	10,311,894	10,240,552
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	11,776,826	11,705,394
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	59,833,526	59,454,242
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	2,852	8,155
Temporary cash investments	107,179	4,760
Total cash and cash equivalents	110,031	12,915
Accounts receivable:
Customer	136,178	154,412
Allowance for doubtful accounts	(6,513)	(13,072)
Associated companies	91,621	29,587
Other	43,337	51,064
Accrued unbilled revenues	95,429	101,663
Total accounts receivable	360,052	323,654
Deferred Fuel Cost	125,767	108,862
Fuel inventory - at average cost	43,693	50,892
Public Utilities, Inventory	262,292	247,980
Deferred nuclear refueling outage costs	51,655	65,318
Prepaid Expense and Other Assets, Current	14,614	14,863
TOTAL	968,104	824,484
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,360,604	1,438,416
Other	791	947
TOTAL	1,361,395	1,439,363
PROPERTY, PLANT, AND EQUIPMENT
Electric	13,637,936	13,578,297
Construction work in progress	306,933	241,127
Nuclear fuel	132,841	182,055
TOTAL PROPERTY, PLANT, AND EQUIPMENT	14,077,710	14,001,479
Less - accumulated depreciation and amortization	5,539,188	5,472,296
PROPERTY, PLANT, AND EQUIPMENT - NET	8,538,522	8,529,183
Regulatory assets:
Other regulatory assets	1,696,876	1,689,678
Deferred Fuel Cost Non Current	68,800	68,751
Other	22,042	13,660
Deferred Costs and Other Assets	1,787,718	1,772,089
TOTAL ASSETS	12,655,739	12,565,119
CURRENT LIABILITIES
Associated companies accounts payable	46,527	217,310
Accounts payable	187,777	190,476
Contract with Customer, Liability, Current	95,178	92,511
Taxes Payable, Current	116,799	89,590
Interest accrued	49,341	17,108
Other	40,881	38,901
TOTAL	536,503	645,896
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,436,824	1,416,201
Accumulated deferred investment tax credits	28,998	29,299
Regulatory liability for income taxes - net	427,203	431,655
Other regulatory liabilities	656,698	743,314
Decommissioning and asset retirement cost liabilities	1,410,540	1,390,410
Loss Contingency Accrual	76,775	77,084
Pension and other postretirement liabilities	165,903	185,789
Long-term debt	4,163,602	3,958,862
Deferred Credits and Other Liabilities	111,271	110,754
TOTAL	8,477,814	8,343,368
Common Shareholders' Equity:
Members' Equity	3,609,699	3,542,745
Members' Equity Attributable to Noncontrolling Interest	31,723	33,110
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	3,641,422	3,575,855
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	12,655,739	12,565,119
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	15,933	195
Temporary cash investments	140,714	18,378
Total cash and cash equivalents	156,647	18,573
Accounts receivable:
Customer	256,931	355,265
Allowance for doubtful accounts	(11,092)	(29,231)
Associated companies	159,787	96,539
Other	49,735	36,674
Accrued unbilled revenues	174,038	174,768
Total accounts receivable	629,399	634,015
Deferred Fuel Cost	44,876	45,374
Fuel inventory - at average cost	43,004	42,958
Public Utilities, Inventory	490,752	485,325
Deferred nuclear refueling outage costs	33,947	39,582
Prepaid Expense and Other Assets, Current	58,384	44,187
TOTAL	1,457,009	1,310,014
Investments in and Advances to Affiliates, at Fair Value	1,390,587	1,390,587
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	2,005,369	2,114,523
Non-utility property - at cost (less accumulated depreciation)	338,365	337,247
Other	13,812	13,744
TOTAL	3,748,133	3,856,101
PROPERTY, PLANT, AND EQUIPMENT
Electric	27,252,039	28,055,038
Natural gas	288,820	285,006
Construction work in progress	721,536	847,924
Nuclear fuel	200,163	209,418
TOTAL PROPERTY, PLANT, AND EQUIPMENT	28,462,558	29,397,386
Less - accumulated depreciation and amortization	9,940,422	9,860,252
PROPERTY, PLANT, AND EQUIPMENT - NET	18,522,136	19,537,134
Regulatory assets:
Other regulatory assets	4,113,282	2,776,666
Deferred Fuel Cost Non Current	168,122	168,122
Other	39,358	27,801
Deferred Costs and Other Assets	4,320,762	2,972,589
TOTAL ASSETS	28,048,040	27,675,838
CURRENT LIABILITIES
Currently maturing long-term debt	200,000	200,000
Associated companies accounts payable	81,781	183,172
Accounts payable	872,120	1,481,902
Contract with Customer, Liability, Current	153,109	150,697
Taxes Payable, Current	21,298	64,248
Interest accrued	92,195	93,052
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	15,182	24,291
Other	56,709	68,995
TOTAL	1,492,394	2,266,357
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,523,361	2,433,854
Accumulated deferred investment tax credits	101,408	102,588
Regulatory liability for income taxes - net	307,779	313,693
Other regulatory liabilities	990,456	1,042,597
Decommissioning and asset retirement cost liabilities	1,673,809	1,653,198
Loss Contingency Accrual	27,185	24,490
Pension and other postretirement liabilities	516,628	528,213
Long-term debt	11,822,131	10,714,346
Deferred Credits and Other Liabilities	387,083	415,930
TOTAL	18,349,840	17,228,909
Common Shareholders' Equity:
Accumulated other comprehensive loss	7,665	8,278
Members' Equity	8,198,141	8,172,294
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,205,806	8,180,572
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	28,048,040	27,675,838
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	26	29
Temporary cash investments	2	47,598
Total cash and cash equivalents	28	47,627
Accounts receivable:
Customer	86,389	84,048
Allowance for doubtful accounts	(3,396)	(7,209)
Associated companies	5,008	42,994
Other	17,994	14,609
Accrued unbilled revenues	50,404	56,034
Total accounts receivable	156,399	190,476
Deferred Fuel Cost	145,954	121,878
Fuel inventory - at average cost	10,288	10,311
Public Utilities, Inventory	75,509	69,639
Prepaid Expense and Other Assets, Current	40,847	6,394
TOTAL	429,025	446,325
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,523	4,527
Escrow accounts	48,888	48,886
TOTAL	53,411	53,413
PROPERTY, PLANT, AND EQUIPMENT
Electric	6,650,580	6,613,109
Construction work in progress	120,538	95,452
TOTAL PROPERTY, PLANT, AND EQUIPMENT	6,771,118	6,708,561
Less - accumulated depreciation and amortization	2,159,949	2,127,590
PROPERTY, PLANT, AND EQUIPMENT - NET	4,611,169	4,580,971
Regulatory assets:
Other regulatory assets	446,131	462,432
Other	18,880	14,248
Deferred Costs and Other Assets	465,011	476,680
TOTAL ASSETS	5,558,616	5,557,389
CURRENT LIABILITIES
Associated companies accounts payable	62,229	42,929
Accounts payable	104,367	113,000
Contract with Customer, Liability, Current	87,307	86,167
Taxes Payable, Current	42,488	106,273
Interest accrued	27,896	17,283
Other	29,735	36,731
TOTAL	354,022	402,383
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	724,154	720,097
Accumulated deferred investment tax credits	10,857	10,913
Regulatory liability for income taxes - net	209,758	212,445
Other regulatory liabilities	73,689	49,313
Decommissioning and asset retirement cost liabilities	10,458	10,315
Loss Contingency Accrual	37,849	38,028
Pension and other postretirement liabilities	55,101	59,065
Long-term debt	2,180,197	2,179,989
Deferred Credits and Other Liabilities	32,608	35,273
TOTAL	3,334,671	3,315,438
Common Shareholders' Equity:
Members' Equity	1,869,923	1,839,568
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,869,923	1,839,568
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	5,558,616	5,557,389
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	26	26
Temporary cash investments	31,139	42,836
Total cash and cash equivalents	31,165	42,862
Securitization recovery trust account	5,098	1,999
Accounts receivable:
Customer	61,442	69,902
Allowance for doubtful accounts	(7,702)	(13,282)
Associated companies	21,557	74,146
Other	12,590	13,668
Accrued unbilled revenues	24,481	25,550
Total accounts receivable	112,368	169,984
Deferred Fuel Cost	2,352	0
Fuel inventory - at average cost	2,499	2,945
Public Utilities, Inventory	20,610	19,216
Prepaid Expense and Other Assets, Current	15,621	5,428
TOTAL	189,713	242,434
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
TOTAL	1,016	1,016
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,964,963	1,976,202
Natural gas	377,826	373,983
Construction work in progress	23,047	22,199
TOTAL PROPERTY, PLANT, AND EQUIPMENT	2,365,836	2,372,384
Less - accumulated depreciation and amortization	785,381	774,309
PROPERTY, PLANT, AND EQUIPMENT - NET	1,580,455	1,598,075
Regulatory assets:
Other regulatory assets	223,118	248,617
Deferred Fuel Cost Non Current	4,080	4,080
Other	60,565	56,101
Deferred Costs and Other Assets	287,763	308,798
TOTAL ASSETS	2,058,947	2,150,323
CURRENT LIABILITIES
Notes Payable, Related Parties, Current	1,326	1,326
Associated companies accounts payable	41,135	45,057
Accounts payable	59,501	146,921
Contract with Customer, Liability, Current	29,470	28,539
Taxes Payable, Current	1,582	4,385
Interest accrued	7,378	7,991
Deferred fuel costs	0	7,607
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	0	1,906
Other	6,019	6,204
TOTAL	146,411	249,936
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	375,056	365,384
Accumulated deferred investment tax credits	16,297	16,306
Regulatory liability for income taxes - net	39,208	40,589
Decommissioning and asset retirement cost liabilities	0	4,032
Loss Contingency Accrual	12,553	6,329
Long-term debt	777,590	777,254
Notes Payable, Related Parties, Noncurrent	9,585	9,585
Deferred Credits and Other Liabilities	28,406	42,193
TOTAL	1,258,695	1,261,672
Common Shareholders' Equity:
Members' Equity	653,841	638,715
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	653,841	638,715
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	2,058,947	2,150,323
Entergy Texas [Member]
Cash and cash equivalents:
Total cash and cash equivalents	26	28
Securitization recovery trust account	9,998	26,629
Accounts receivable:
Customer	88,964	83,797
Allowance for doubtful accounts	(2,783)	(5,814)
Associated companies	15,868	31,720
Other	23,315	13,404
Accrued unbilled revenues	61,658	62,241
Total accounts receivable	187,022	185,348
Deferred Fuel Cost	56,720	48,280
Fuel inventory - at average cost	34,673	42,712
Public Utilities, Inventory	73,415	72,884
Prepaid Expense and Other Assets, Current	23,902	17,515
TOTAL	385,756	393,396
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	287	300
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	17,730	18,128
TOTAL	18,393	18,804
PROPERTY, PLANT, AND EQUIPMENT
Electric	7,071,317	7,181,567
Construction work in progress	207,167	183,965
TOTAL PROPERTY, PLANT, AND EQUIPMENT	7,278,484	7,365,532
Less - accumulated depreciation and amortization	2,053,212	2,049,750
PROPERTY, PLANT, AND EQUIPMENT - NET	5,225,272	5,315,782
Regulatory assets:
Other regulatory assets	556,412	421,333
Other	119,734	112,096
Deferred Costs and Other Assets	676,146	533,429
TOTAL ASSETS	6,305,567	6,261,411
CURRENT LIABILITIES
Associated companies accounts payable	225,441	142,929
Accounts payable	140,760	164,981
Contract with Customer, Liability, Current	37,535	37,271
Taxes Payable, Current	33,830	49,018
Interest accrued	7,807	19,002
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	20,059	27,188
Other	15,797	16,120
TOTAL	481,229	456,509
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	695,150	692,496
Accumulated deferred investment tax credits	9,172	9,325
Regulatory liability for income taxes - net	137,959	144,145
Other regulatory liabilities	38,884	37,060
Decommissioning and asset retirement cost liabilities	8,638	8,520
Loss Contingency Accrual	8,296	8,242
Long-term debt	2,325,371	2,354,148
Deferred Credits and Other Liabilities	67,777	67,760
TOTAL	$ 3,291,247	$ 3,321,696
Common Stock, Shares, Outstanding	46,525,000	46,525,000
Common Shareholders' Equity:
Common Stock, Value, Issued	$ 49,452	$ 49,452
Additional Paid in Capital, Common Stock	1,050,125	1,050,125
TOTAL	2,494,341	2,444,456
Stockholders' Equity Attributable to Noncontrolling Interest	38,750	38,750
Retained Earnings (Accumulated Deficit)	1,394,764	1,344,879
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,533,091	2,483,206
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	6,305,567	6,261,411
System Energy [Member]
Cash and cash equivalents:
Cash	72	87
Temporary cash investments	98,183	89,114
Total cash and cash equivalents	98,255	89,201
Accounts receivable:
Associated companies	102,258	118,977
Other	8,961	7,003
Total accounts receivable	111,219	125,980
Public Utilities, Inventory	124,639	127,093
Deferred nuclear refueling outage costs	32,250	10,123
Prepaid Expense and Other Assets, Current	2,843	1,870
TOTAL	369,206	354,267
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,308,172	1,385,254
TOTAL	1,308,172	1,385,254
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,357,646	5,362,494
Construction work in progress	149,025	97,968
Nuclear fuel	210,446	171,438
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,717,117	5,631,900
Less - accumulated depreciation and amortization	3,414,249	3,396,136
PROPERTY, PLANT, AND EQUIPMENT - NET	2,302,868	2,235,764
Regulatory assets:
Other regulatory assets	397,877	395,546
Other	1,728	1,793
Deferred Costs and Other Assets	399,605	397,339
TOTAL ASSETS	4,379,851	4,372,624
CURRENT LIABILITIES
Currently maturing long-term debt	50,335	50,329
Associated companies accounts payable	11,736	23,682
Accounts payable	70,571	62,573
Taxes Payable, Current	38,857	32,918
Interest accrued	11,239	11,714
Other	4,101	4,101
TOTAL	186,839	185,317
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	373,447	382,931
Accumulated deferred investment tax credits	42,684	43,003
Regulatory liability for income taxes - net	111,511	113,165
Other regulatory liabilities	660,943	744,944
Decommissioning and asset retirement cost liabilities	1,017,520	1,007,603
Pension and other postretirement liabilities	71,562	76,104
Long-term debt	755,018	690,967
Deferred Credits and Other Liabilities	37,535	37,230
TOTAL	$ 3,070,220	$ 3,095,947
Common Stock, Shares, Outstanding	789,350	789,350
Common Shareholders' Equity:
Common Stock, Value, Issued	$ 951,850	$ 951,850
Retained Earnings (Accumulated Deficit)	170,942	139,510
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,122,792	1,091,360
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 4,379,851	$ 4,372,624

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Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net income	$ 279,593	$ 339,145
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, after Tax	24	(29,580)
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	8,328	22,967
Net unrealized investment gains	(12,402)	(44,687)
Other comprehensive income (loss)	(4,050)	(51,300)
Total comprehensive income	275,543	287,845
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	3,193	4,580
Comprehensive Income Attributable to Entergy Corporation	272,350	283,265
Entergy Louisiana [Member]
Net income	150,860	166,626
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	(613)	(407)
Other comprehensive income (loss)	(613)	(407)
Total comprehensive income	150,247	166,219
Entergy Arkansas [Member]
Net income	65,567	93,037
Other comprehensive income (loss)
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	(1,387)	0
System Energy [Member]
Net income	$ 31,432	$ 23,864

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Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands	Total	Subsidiaries Preferred Stock [Member]	Paid In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]	Common Stock [Member]	Treasury Stock [Member]	Entergy Texas [Member]	Entergy Texas [Member] Subsidiaries Preferred Stock [Member]	Entergy Texas [Member] Paid In Capital [Member]	Entergy Texas [Member] Retained Earnings [Member]	Entergy Texas [Member] Common Stock [Member]	Entergy Mississippi [Member]	Entergy Arkansas [Member]	Entergy Arkansas [Member] Member's Equity [Member]	Entergy Arkansas [Member] Noncontrolling Interest	Entergy Louisiana [Member]	Entergy Louisiana [Member] Member's Equity [Member]	Entergy Louisiana [Member] Accumulated Other Comprehensive Income [Member]	Entergy New Orleans [Member]	System Energy [Member]	System Energy [Member] Retained Earnings [Member]	System Energy [Member] Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 10,961,142	$ 35,000	$ 6,549,923	$ 9,897,182	$ (449,207)	$ 2,700	$ (5,074,456)	$ 2,157,578	$ 35,000	$ 955,162	$ 1,117,964	$ 49,452	$ 1,672,734	$ 3,276,169	$ 3,276,169	$ 0	$ 7,457,688	$ 7,453,361	$ 4,327	$ 606,917	$ 1,080,546	$ 128,696	$ 951,850
Consolidated net income	339,145	4,580	0	334,565	0	0	0	50,058	0	0	50,058	0	25,972	93,037	93,037	0	166,626	166,626	0	1,771	23,864	23,864	0
Dividends, Common Stock, Cash	(190,595)	0	0	(190,595)	0	0	0														(21,000)	(21,000)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,580)	(4,580)	0	0	0	0	0
Other comprehensive income (loss)	(51,300)	0	0	0	(51,300)	0	0										(407)	0	(407)
Common stock issuances related to stock plans	1,636	0	29,871	0	0	0	(28,235)
Other																	(16)	(16)	0
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,580							470						0
Dividends, Preferred Stock, Cash	$ 4,000							470	0	0	470	0
Common stock dividend (in dollars per share)	$ 0.95
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 11,052,176	35,000	6,520,052	10,041,152	(500,507)	2,700	(5,046,221)	2,207,166	35,000	955,162	1,167,552	49,452	1,698,706	3,369,206	3,369,206	0	7,623,891	7,619,971	3,920	608,688	1,083,410	131,560	951,850
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	11,705,394	68,110	6,766,239	10,240,552	(332,528)	2,720	(5,039,699)	2,483,206	38,750	1,050,125	1,344,879	49,452	1,839,568	3,575,855	3,542,745	33,110	8,180,572	8,172,294	8,278	638,715	1,091,360	139,510	951,850
Consolidated net income	279,593	3,193	0	276,400	0	0	0	50,403	0	0	50,403	0	30,355	65,567	66,954	(1,387)	150,860	150,860	0	15,126	31,432	31,432	0
Dividends, Common Stock, Cash	(205,058)	0	0	(205,058)	0	0	0										(125,000)	(125,000)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,580)	(4,580)	0	0	0	0	0
Other comprehensive income (loss)	(4,050)	0	0	0	(4,050)	0	0										(613)	0	(613)
Common stock issuances related to stock plans	(5,527)	0	31,085	0	0	0	(36,612)
Other																	(13)	(13)	0
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	3,193							518						(1,387)
Dividends, Preferred Stock, Cash	$ 4,000							518	0	0	518	0
Common stock dividend (in dollars per share)	$ 1.01
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 11,776,826	$ 66,723	$ 6,735,154	$ 10,311,894	$ (336,578)	$ 2,720	$ (5,003,087)	$ 2,533,091	$ 38,750	$ 1,050,125	$ 1,394,764	$ 49,452	$ 1,869,923	$ 3,641,422	$ 3,609,699	$ 31,723	$ 8,205,806	$ 8,198,141	$ 7,665	$ 653,841	$ 1,122,792	$ 170,942	$ 951,850

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Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Securitized Regulatory Transition Assets, Noncurrent	$ 34,145	$ 49,579
Long-term Transition Bond, Noncurrent	$ 54,674	$ 83,639
Common Stock, Shares Authorized	499,000,000	499,000,000
Common Stock, Shares, Issued	271,965,510	271,965,510
Preferred Stock, Shares Issued	0	0
Preferred Stock, Shares Authorized	1,000,000	1,000,000
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Treasury Stock, Shares	68,808,788	69,312,326
Entergy New Orleans [Member]
Securitized Regulatory Transition Assets, Noncurrent	$ 22,924	$ 25,761
Long-term Transition Bond, Noncurrent	29,721	29,661
Entergy Texas [Member]
Securitized Regulatory Transition Assets, Noncurrent	11,221	23,818
Long-term Transition Bond, Noncurrent	$ 24,953	$ 53,979
Common Stock, Shares Authorized	200,000,000	200,000,000
Common Stock, Shares, Issued	46,525,000	46,525,000
Common Stock, Shares, Outstanding	46,525,000	46,525,000
System Energy [Member]
Common Stock, Shares Authorized	1,000,000	1,000,000
Common Stock, Shares, Issued	789,350	789,350
Common Stock, Shares, Outstanding	789,350	789,350

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Consolidated Statements of Comprehensive Income (Parentheticals) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 2,542	$ 6,314
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, Tax	0	7,869
Other Comprehensive Income (Loss), Securities, Available-for-sale, Tax	7,221	25,581
Entergy Louisiana [Member]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 226	$ 144

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2022

Commitments And Contingencies

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

Entergy Arkansas [Member]

Commitments And Contingencies

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

Entergy Louisiana [Member]

Commitments And Contingencies

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

Entergy Mississippi [Member]

Commitments And Contingencies

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

Entergy New Orleans [Member]

Commitments And Contingencies

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

Entergy Texas [Member]

Commitments And Contingencies

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

System Energy [Member]

Commitments And Contingencies

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf - Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

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Rate And Regulatory Matters

3 Months Ended

Mar. 31, 2022

Rate and Regulatory Matters

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

Entergy Arkansas [Member]

Rate and Regulatory Matters

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

Entergy Louisiana [Member]

Rate and Regulatory Matters

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

Entergy Mississippi [Member]

Rate and Regulatory Matters

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

Entergy New Orleans [Member]

Rate and Regulatory Matters

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

Entergy Texas [Member]

Rate and Regulatory Matters

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

System Energy [Member]

Rate and Regulatory Matters

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2022, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase from $0.00959 per kWh to $0.01785 per kWh. The primary reason for the rate increase is a large under-recovery balance as a result of higher natural gas prices in 2021, particularly in the fourth quarter 2021. At the request of the APSC general staff, Entergy Arkansas deferred its request for recovery of $32 million from the under-recovery related to the 2021 February winter storms until the 2023 energy cost rate redetermination, unless a request for an interim adjustment to the energy cost recovery rider is necessary. This resulted in a redetermined rate of $0.016390 per kWh, which became effective with the first billing cycle in April 2022 through the normal operation of the tariff.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. As of March 31, 2022, Entergy Arkansas had a regulatory asset of $34.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of March 31, 2022, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022, subject to refund, pending a final MPSC order. A final order is expected in the second quarter 2022, with the resulting final rates, including amounts above the 2% cap of 2021 retail revenues, effective July 2022.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. As of March 31, 2022, Entergy Mississippi had a regulatory asset of $14.1 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2022 Formula Rate Plan Filing

In April 2022, Entergy New Orleans submitted to the City Council its formula rate plan 2021 test year filing. The 2021 test year evaluation report produced an earned return on equity of 6.88% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $40.2 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $32.3 million and an increase in authorized gas revenues of $3.2 million. Entergy New Orleans also seeks to commence collecting $4.7 million in electric revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of September 2022 pursuant to the formula rate plan

tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments.

COVID-19 Orders

As discussed in the Form 10-K, in May 2020 the City Council issued an accounting order authorizing Entergy New Orleans to establish a regulatory asset for incremental COVID-19-related expenses. As of March 31, 2022, Entergy New Orleans had a regulatory asset of $14.5 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in August 2021, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.2 million annually, or $13.9 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between September 1, 2020 and June 30, 2021. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in December 2021. In December 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding, including a motion for interim rates to take effect for usage on and after January 24, 2022. Also, in December 2021, the ALJ with the State Office of Administrative Hearings issued an order granting the motion for interim rates, which went into effect in January 2022, admitting evidence, and remanding the proceeding to the PUCT to consider the settlement. In March 2022 the PUCT issued an order approving the settlement.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its generation capital investment in the Montgomery County Power Station through August 31, 2020, which was approved by the PUCT on an interim basis in January 2021. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include its generation capital investment in Montgomery County Power Station after August 31, 2020 and an unopposed settlement agreement filed on behalf of the parties by Entergy Texas in October 2021 was approved by the PUCT in January 2022. In February 2022, Entergy Texas filed a relate-back rider to collect over five months an additional approximately $5 million, which is the difference between the interim revenue requirement approved in January 2021 and the revenue requirement approved in January 2022 that reflects Entergy Texas’s full generation capital investment and ownership in Montgomery County Power Station on January 1, 2021, plus carrying costs from January 2021 through January 2022 when the updated revenue requirement took effect. In April 2022, Entergy Texas and PUCT staff filed a joint proposed order that supports approval of Entergy Texas’s as-filed request.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represented no change from the generation cost recovery rider rates established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. In September 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. A procedural schedule was established with a hearing scheduled in April 2022. In January 2022, Entergy Texas filed an update to its application to align the requested revenue requirement with the terms of the generation cost recovery rider settlement approved by the PUCT in January 2022. In March 2022, Entergy Texas filed on

behalf of the parties an unopposed motion, which motion was granted by the ALJ with the State Office of Administrative Hearings, to abate the procedural schedule indicating that the parties had reached an agreement in principle. In April 2022, Entergy Texas filed on behalf of the parties a unanimous settlement agreement that would adjust its generation cost recovery rider to recover an annual revenue requirement of approximately $92.8 million, which is $4.5 million in incremental annual revenue above the $88.3 million approved in January 2022, related to Entergy Texas’s actual investment in the acquisition of the Hardin County Peaking Facility.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings, the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. As of March 31, 2022, Entergy Texas had a regulatory asset of $10.4 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of the opportunity sales payments made to the other Utility operating companies. In October 2020 the APSC filed a motion to dismiss Entergy Arkansas’s complaint. In March 2022 the court denied the APSC’s motion to dismiss and, in April 2022, issued a scheduling order including a trial date in February 2023.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. The following are updates to that discussion.

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $61 million, which includes interest through March 31, 2022, and the estimated resulting annual rate reduction would be approximately $50 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $38 million, including interest, as of March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on

exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through March 31, 2022, is approximately $422 million, plus interest, which is approximately $135 million through March 31, 2022. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through March 31, 2022.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement.

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in

abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal was initially stayed for a period of 90 days, but the stay expired. In November 2021 the Fifth Circuit dismissed the appeal as premature.

In November 2021 the LPSC, APSC, and City Council filed direct testimony and requested the FERC to order refunds for prior periods and prospective amendments to the Unit Power Sales Agreement. The LPSC’s refund claims include, among other things, allegations that: (1) System Energy should not have included certain sale-leaseback transaction costs in prepayments; (2) System Energy should have credited rate base to reflect the time value of money associated with the advance collection of lease payments; (3) System Energy incorrectly included refueling outage costs that were recorded in account 174 in rate base; and (4) System Energy should have excluded several accumulated deferred income tax balances in account 190 from rate base. The LPSC is also seeking a retroactive adjustment to retained earnings and capital structure in conjunction with the implementation of its proposed refunds. In addition, the LPSC seeks amendments to the Unit Power Sales Agreement going forward to address below-the-line costs, incentive compensation, the working capital allowance, litigation expenses, and the 2019 termination of the capital funds agreement. The APSC argues that: (1) System Energy should have included borrowings from the Entergy System money pool in its determination of short-term debt in its cost of capital; and (2) System Energy should credit customers with System Energy’s allocation of earnings on money pool investments. The City Council alleges that System Energy has maintained excess cash on hand in the money pool and that retention of excess cash was imprudent. Based on this allegation, the City Council’s witness recommends a refund of approximately $98.8 million for the period 2004-September 2021 or other alternative relief. The City Council further recommends that the FERC impose a hypothetical equity ratio such as 48.15% equity to capital on a prospective basis.

In January 2022, System Energy filed answering testimony arguing that the FERC should not order refunds for prior periods or any prospective amendments to the Unit Power Sales Agreement. In response to the LPSC’s refund claims, System Energy argues, among other things, that (1) the inclusion of sale-leaseback transaction costs in prepayments was correct; (2) the filed rate doctrine bars the request for a retroactive credit to rate base for the time value of money associated with the advance collection of lease payments; (3) an accounting misclassification for deferred refueling outage costs has been corrected, caused no harm to customers, and requires no refunds; and (4) its accounting and ratemaking treatment of specified accumulated deferred income tax balances in account 190 has been correct. System Energy further responds that no retroactive adjustment to retained earnings or capital structure should be ordered because there is no general policy requiring such a remedy and there was no showing that the retained earnings element of the capital structure was incorrectly implemented. Further, System Energy presented evidence that all of the costs that are being challenged were long known to the retail regulators and were approved by them for inclusion in retail rates, and the attempt to retroactively challenge these costs, some of which have been included in rates for decades, is unjust and unreasonable. In response to the LPSC’s proposed going-forward adjustments, System Energy presents evidence to show that none of the proposed adjustments are needed. On the issue of below-the-line expenses, during discovery procedures, System Energy identified a historical allocation error in certain months and agreed to provide a bill credit to customers to correct the error. In response to the APSC’s claims, System Energy argues that the Unit Power Sales Agreement does not include System Energy’s borrowings from the Entergy System money pool or earnings on deposits to the Entergy System money pool in the determination of the cost of capital; and accordingly, no refunds are appropriate on those issues. In response to the City Council’s claims, System Energy argues that it has reasonably managed its cash and that the City Council’s theory of cash management is defective because it fails to adequately consider the relevant cash needs of System Energy and it makes faulty presumptions about the operation of the Entergy System money pool. System Energy further points out that the issue of its capital structure is already subject to pending FERC litigation.

In March 2022 the FERC trial staff filed direct and answering testimony in response to the LPSC, APSC, and City Council’s direct testimony. In its testimony, the FERC trial staff recommends refunds for two primary reasons: (1) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with rate refunds; and (2) it concluded that System Energy should have excluded specified accumulated deferred income tax balances in account 190 associated with a deemed contract satisfaction and reissuance that occurred in 2005. The FERC trial staff recommends refunds of $84.1 million, exclusive of any tax gross-up or FERC interest. In addition, the FERC trial staff recommends the following prospective modifications to the Unit Power Sales Agreement: (1) inclusion of a rate base credit to recognize the time value of money associated with the advance collection of lease payments; (2) exclusion of executive incentive compensation costs for members of the Office of the Chief Executive and long-term performance unit costs where awards are based solely or primarily on financial metrics; and (3) exclusion of unvested, accrued amounts for stock options, performance units, and restricted stock awards. With respect to issues that ultimately concern the reasonableness of System Energy’s rate of return, the FERC trial staff states that it is unnecessary to consider such issues in this proceeding, in light of the pending case concerning System Energy’s return on equity and capital structure. On all other material issues raised by the LPSC, APSC, and City Council, the FERC trial staff recommends either no refunds or no modification to the Unit Power Sales Agreement.

System Energy Formula Rate Annual Protocols Formal Challenge Concerning 2020 Calendar Year Bills

System Energy’s Unit Power Sales Agreement includes formula rate protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In February 2022, pursuant to the protocols procedures, the LPSC, the APSC, the MPSC, the City Council, and the Mississippi Public Utilities Staff filed with the FERC a formal challenge to System Energy’s implementation of the formula rate during calendar year 2020. The formal challenge alleges: (1) that it was imprudent for System Energy to accept the IRS’s partial acceptance of a previously uncertain tax position; (2) that System Energy should have delayed recording the result of the IRS’s partial acceptance of the previously uncertain tax position until after internal tax allocation payments were made; (3) that the equity ratio charged in rates was excessive; (4) that sale-leaseback rental payments should have been excluded from rates; and (5) that all issues in the ongoing Unit Power Sales Agreement Complaint proceeding should also be reflected in calendar year 2020 bills. While System Energy disagrees that any refunds are owed for the 2020 calendar year bills, the formal challenge estimates that the financial impact of the first through fourth allegations is approximately $53 million; it does not provide an estimate of the financial impact of the fifth allegation.

In March 2022, System Energy filed an answer to the formal challenge in which it requested that the FERC deny the formal challenge as a matter of law, or else hold the proceeding in abeyance pending the resolution of related dockets.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following are updates to that discussion.

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild. In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice

accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms were estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana was seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, was eligible for recovery from customers. Additionally, Entergy Louisiana was requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million was appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

In August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review.

After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests in regard to Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contained the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and were eligible for recovery; carrying costs of $51 million were recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana was authorized to finance $3.186 billion utilizing the securitization process authorized by Act 55, as supplemented by Act 293. The LPSC issued an order approving the settlement in March 2022. As a result of the financing order, in first quarter 2022, Entergy Louisiana reclassified $1.339 billion from utility plant to other regulatory assets. The securitization process is expected to be completed in second quarter 2022.

In April 2022, Entergy Louisiana filed an application with the LPSC relating to Hurricane Ida restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by Hurricane Ida currently are estimated to be approximately $2.54 billion, including approximately $1.96 billion in capital costs and approximately $586 million in non-capital costs. Including carrying costs through December 2022, Entergy Louisiana is seeking an LPSC determination that $2.60 billion was prudently incurred and, therefore, is eligible for recovery from customers. As part of this filing, Entergy Louisiana also is seeking an LPSC determination that an additional $32 million in restoration costs associated with the restoration of Entergy Louisiana’s electric facilities damaged by Hurricane Laura, Hurricane Delta, and Hurricane Zeta as well as Winter Storm Uri was prudently incurred. This amount is exclusive of the requested $3 million in carrying costs through December 2022. In total, Entergy Louisiana is requesting an LPSC determination that $2.64 billion was prudently incurred and, therefore, is eligible for recovery from customers. As discussed above, in March 2022 the LPSC approved financing of a $1 billion storm escrow that can be withdrawn to finance costs associated with Hurricane Ida restoration. Entergy Louisiana expects to supplement the April 2022 application with a request that the LPSC authorize Entergy Louisiana to finance the remaining storm restoration costs included in the April 2022 application,

currently expected to be through the securitization process authorized by Louisiana Act 55, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

As discussed in the Form 10-K, in August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of certain system restoration costs, which were approved by the PUCT as eligible for securitization in December 2021. In November 2021 the parties filed an unopposed settlement agreement supporting the issuance of a financing order consistent with Entergy Texas’s application and with minor adjustments to certain upfront and ongoing costs to be incurred to facilitate the issuance and serving of system restoration bonds. In January 2022 the PUCT issued a financing order consistent with the unopposed settlement. As a result of the financing order, in first quarter 2022, Entergy Texas reclassified $153 million from utility plant to other regulatory assets.

In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds). With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas began cost recovery through the system restoration charge effective with the first billing cycle of May 2022 and the system restoration charge is expected to remain in place up to 15 years. See Note 4 to the financial statements herein for a discussion of the April 2022 issuance of the securitization bonds.

XML

Equity

3 Months Ended

Mar. 31, 2022

Equity

EQUITY (Entergy Corporation and Entergy Louisiana)

Common Stock

Earnings per Share

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:

	For the Three Months Ended March 31,
	2022			2021
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$276.4	202.9	$1.36	$334.6	200.5	$1.67
Average dilutive effect of:
Stock options		0.5	—		0.4	(0.01)
Other equity plans		0.4	—		0.2	—
Equity forwards		0.1	—		—	—
Diluted earnings per share	$276.4	203.9	$1.36	$334.6	201.1	$1.66

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.9 million for the three months ended March 31, 2022 and approximately 1 million for the three months ended March 31, 2021.

Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K.

Dividends declared per common share were $1.01 for the three months ended March 31, 2022 and $0.95 for the three months ended March 31, 2021.

Equity Distribution Program

In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion, of which an aggregate gross sales price of approximately $633 million has been sold through March 31, 2022. See Note 7 to the financial statements in the Form 10-K for discussion of the common stock issued and unsettled forward sale agreements entered into during 2021. For the three months ended March 31, 2022, there were no shares of common stock issued under the at the market equity distribution program.

In March 2022, Entergy entered into a forward sale agreement for 1,538,010 shares of common stock. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreement occur. The forward sale agreement requires Entergy to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 1,538,010 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $108.14 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million. In connection with the sale of these shares, Entergy paid the forward sellers fees of approximately $1.7 million, which have not been deducted from the gross sales price. Entergy did not receive any proceeds from such sales of borrowed shares.

Until settlement of the forward sale agreement, earnings per share dilution resulting from the agreement, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. For the three months ended March 31, 2022, 1,775,251 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.

Treasury Stock

During the three months ended March 31, 2022, Entergy Corporation issued 503,538 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the three months ended March 31, 2022.

Retained Earnings

On April 11, 2022, Entergy Corporation’s Board of Directors declared a common stock dividend of $1.01 per share, payable on June 1, 2022 to holders of record as of May 5, 2022.

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2022 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2022	($1,035)	($338,647)	$7,154	($332,528)
Other comprehensive income (loss) before reclassifications	(14)	—	(15,875)	(15,889)
Amounts reclassified from accumulated other comprehensive income (loss)	38	8,328	3,473	11,839
Net other comprehensive income (loss) for the period	24	8,328	(12,402)	(4,050)
Ending balance, March 31, 2022	($1,011)	($330,319)	($5,248)	($336,578)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2021 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2021	$28,719	($534,576)	$56,650	($449,207)
Other comprehensive income (loss) before reclassifications	1,482	—	(45,301)	(43,819)
Amounts reclassified from accumulated other comprehensive income (loss)	(31,062)	22,967	614	(7,481)
Net other comprehensive income (loss) for the period	(29,580)	22,967	(44,687)	(51,300)
Ending balance, March 31, 2021	($861)	($511,609)	$11,963	($500,507)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2022 and 2021:

	Pension and Other Postretirement Liabilities
	2022	2021
	(In Thousands)
Beginning balance, January 1,	$8,278	$4,327
Amounts reclassified from accumulated other comprehensive income (loss)	(613)	(407)
Net other comprehensive income (loss) for the period	(613)	(407)
Ending balance, March 31,	$7,665	$3,920

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$—	$39,367	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	(48)	39,319
Income taxes	10	(8,257)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	($38)	$31,062
Pension and other postretirement liabilities
Amortization of prior-service credit	$3,837	$5,248	(a)
Amortization of loss	(13,925)	(34,529)	(a)
Settlement loss	(782)	—	(a)
Total amortization	(10,870)	(29,281)
Income taxes	2,542	6,314	Income taxes
Total amortization (net of tax)	($8,328)	($22,967)
Net unrealized investment gain (loss)
Realized gain (loss)	($5,495)	($972)	Interest and investment income
Income taxes	2,022	358	Income taxes
Total realized investment gain (loss) (net of tax)	($3,473)	($614)
Total reclassifications for the period (net of tax)	($11,839)	$7,481

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,158	$1,230	(a)
Amortization of loss	(319)	(679)	(a)
Total amortization	839	551
Income taxes	(226)	(144)	Income taxes
Total amortization (net of tax)	613	407
Total reclassifications for the period (net of tax)	$613	$407

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Entergy Louisiana [Member]

Equity

EQUITY (Entergy Corporation and Entergy Louisiana)

Common Stock

Earnings per Share

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:

	For the Three Months Ended March 31,
	2022			2021
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$276.4	202.9	$1.36	$334.6	200.5	$1.67
Average dilutive effect of:
Stock options		0.5	—		0.4	(0.01)
Other equity plans		0.4	—		0.2	—
Equity forwards		0.1	—		—	—
Diluted earnings per share	$276.4	203.9	$1.36	$334.6	201.1	$1.66

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.9 million for the three months ended March 31, 2022 and approximately 1 million for the three months ended March 31, 2021.

Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K.

Dividends declared per common share were $1.01 for the three months ended March 31, 2022 and $0.95 for the three months ended March 31, 2021.

Equity Distribution Program

In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion, of which an aggregate gross sales price of approximately $633 million has been sold through March 31, 2022. See Note 7 to the financial statements in the Form 10-K for discussion of the common stock issued and unsettled forward sale agreements entered into during 2021. For the three months ended March 31, 2022, there were no shares of common stock issued under the at the market equity distribution program.

In March 2022, Entergy entered into a forward sale agreement for 1,538,010 shares of common stock. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreement occur. The forward sale agreement requires Entergy to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 1,538,010 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $108.14 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million. In connection with the sale of these shares, Entergy paid the forward sellers fees of approximately $1.7 million, which have not been deducted from the gross sales price. Entergy did not receive any proceeds from such sales of borrowed shares.

Until settlement of the forward sale agreement, earnings per share dilution resulting from the agreement, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. For the three months ended March 31, 2022, 1,775,251 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.

Treasury Stock

During the three months ended March 31, 2022, Entergy Corporation issued 503,538 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the three months ended March 31, 2022.

Retained Earnings

On April 11, 2022, Entergy Corporation’s Board of Directors declared a common stock dividend of $1.01 per share, payable on June 1, 2022 to holders of record as of May 5, 2022.

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2022 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2022	($1,035)	($338,647)	$7,154	($332,528)
Other comprehensive income (loss) before reclassifications	(14)	—	(15,875)	(15,889)
Amounts reclassified from accumulated other comprehensive income (loss)	38	8,328	3,473	11,839
Net other comprehensive income (loss) for the period	24	8,328	(12,402)	(4,050)
Ending balance, March 31, 2022	($1,011)	($330,319)	($5,248)	($336,578)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2021 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2021	$28,719	($534,576)	$56,650	($449,207)
Other comprehensive income (loss) before reclassifications	1,482	—	(45,301)	(43,819)
Amounts reclassified from accumulated other comprehensive income (loss)	(31,062)	22,967	614	(7,481)
Net other comprehensive income (loss) for the period	(29,580)	22,967	(44,687)	(51,300)
Ending balance, March 31, 2021	($861)	($511,609)	$11,963	($500,507)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2022 and 2021:

	Pension and Other Postretirement Liabilities
	2022	2021
	(In Thousands)
Beginning balance, January 1,	$8,278	$4,327
Amounts reclassified from accumulated other comprehensive income (loss)	(613)	(407)
Net other comprehensive income (loss) for the period	(613)	(407)
Ending balance, March 31,	$7,665	$3,920

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$—	$39,367	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	(48)	39,319
Income taxes	10	(8,257)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	($38)	$31,062
Pension and other postretirement liabilities
Amortization of prior-service credit	$3,837	$5,248	(a)
Amortization of loss	(13,925)	(34,529)	(a)
Settlement loss	(782)	—	(a)
Total amortization	(10,870)	(29,281)
Income taxes	2,542	6,314	Income taxes
Total amortization (net of tax)	($8,328)	($22,967)
Net unrealized investment gain (loss)
Realized gain (loss)	($5,495)	($972)	Interest and investment income
Income taxes	2,022	358	Income taxes
Total realized investment gain (loss) (net of tax)	($3,473)	($614)
Total reclassifications for the period (net of tax)	($11,839)	$7,481

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,158	$1,230	(a)
Amortization of loss	(319)	(679)	(a)
Total amortization	839	551
Income taxes	(226)	(144)	Income taxes
Total amortization (net of tax)	613	407
Total reclassifications for the period (net of tax)	$613	$407

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

XML

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

3 Months Ended

Mar. 31, 2022

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Arkansas [Member]

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Louisiana [Member]

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Mississippi [Member]

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy New Orleans [Member]

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Texas [Member]

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

System Energy [Member]

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the three months ended March 31, 2022 was 1.81% on the drawn portion of the facility.  As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of March 31, 2022, Entergy Corporation had $1.343 billion of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2022 was 0.48%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its

obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of March 31, 2022, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the three months ended March 31, 2022 was 1.72% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through October 2023 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances

(Entergy Arkansas)

In March 2022, Entergy Arkansas issued $200 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas expects to use the proceeds for general corporate purposes, including the repayment of borrowings from the Entergy System money pool.

(Entergy Louisiana)

In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. The weighted average interest rate for the three months ended March 31, 2022 was 0.976%. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida.

Entergy Texas Securitization Bonds

In January 2022, the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’ Hurricanes Laura and Delta and Winter Storm Uri restoration costs, plus carrying costs, plus $13.3 million relating to a system restoration regulatory asset, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured restoration bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Restoration Bonds:
Tranche A-1 (3.051%) due December 2028	$100,000
Tranche A-2 (3.697%) due December 2036	190,850
Total senior secured restoration bonds	$290,850

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next five years in the amounts of $12.3 million for 2022, $17.8 million for 2023, $18.3 million for 2024, $18.8 million for 2025, and $19.4 million for 2026. All of the expected principal payments for 2022-2026 are for Tranche A-1.

With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

XML

Stock-Based Compensation

3 Months Ended

Mar. 31, 2022

Entergy Corporation [Member]

Stock-Based Compensation

STOCK-BASED COMPENSATION (Entergy Corporation)

Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K.  Awards under Entergy’s plans generally vest over three years.

Stock Options

Entergy granted options on 444,028 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2022 with a fair value of $16.25 per option.  As of March 31, 2022, there were options on 3,128,304 shares of common stock outstanding with a weighted-average exercise price of $94.35.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference

between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of March 31, 2022.  The aggregate intrinsic value of the stock options outstanding as of March 31, 2022 was $77.6 million.

The following table includes financial information for outstanding stock options for the three months ended March 31, 2022 and 2021:

	2022	2021
	(In Millions)
Compensation expense included in Entergy’s consolidated net income	$1.1	$1.0
Tax benefit recognized in Entergy’s consolidated net income	$0.3	$0.3
Compensation cost capitalized as part of fixed assets and materials and supplies	$0.4	$0.4

Other Equity Awards

In January 2022 the Board approved and Entergy granted 328,849 restricted stock awards and 170,966 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on January 27, 2022 and were valued at $109.59 per share, which was the closing price of Entergy’s common stock on that date.  Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period. One-third of the restricted stock awards and accrued dividends will vest upon each anniversary of the grant date.  

In addition, long-term incentive awards were also granted in the form of performance units that represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. To emphasize the importance of strong cash generation for the long-term health of its business, a credit measure – adjusted funds from operations/debt ratio – was selected for the 2022-2024 performance period. Performance will be measured based eighty percent on relative total shareholder return and twenty percent on the credit measure.  The performance units were granted on January 27, 2022 and eighty percent were valued at $138.99 per share based on various factors, primarily market conditions; and twenty percent were valued at $109.59 per share, the closing price of Entergy’s common stock on that date.  Performance units have the same dividend rights as shares of Entergy common stock and are considered issued and outstanding shares of Entergy upon vesting. Performance units are expensed ratably over the three-year vesting period and compensation cost for the portion of the award based on cumulative adjusted earnings per share will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program.

The following table includes financial information for other outstanding equity awards for the three months ended March 31, 2022 and 2021:

	2022	2021
	(In Millions)
Compensation expense included in Entergy’s consolidated net income	$11.4	$10.8
Tax benefit recognized in Entergy’s consolidated net income	$2.9	$2.7
Compensation cost capitalized as part of fixed assets and materials and supplies	$4.4	$4.0

XML

Retirement And Other Postretirement Benefits

3 Months Ended

Mar. 31, 2022

Retirement And Other Postretirement Benefits

RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Arkansas [Member]

Retirement And Other Postretirement Benefits

RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Louisiana [Member]

Retirement And Other Postretirement Benefits

RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Mississippi [Member]

Retirement And Other Postretirement Benefits

RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy New Orleans [Member]

Retirement And Other Postretirement Benefits

RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Texas [Member]

Retirement And Other Postretirement Benefits

RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

System Energy [Member]

Retirement And Other Postretirement Benefits

RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Non-Qualified Net Pension Cost

Entergy recognized $10.2 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2022 and 2021, respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2022 were settlement charges of $5.3 million related to the payment of lump sum benefits out of the plan. In the first quarter of 2021 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At March 31, 2022, the balance in this reserve was approximately $14.5 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $200 million to its qualified pension plans in 2022.  As of March 31, 2022, Entergy had contributed $67.9 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

XML

Business Segment Information

3 Months Ended

Mar. 31, 2022

Business Segment Information

BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Entergy Arkansas [Member]

Business Segment Information

BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Entergy Louisiana [Member]

Business Segment Information

BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Entergy Mississippi [Member]

Business Segment Information

BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Entergy New Orleans [Member]

Business Segment Information

BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Entergy Texas [Member]

Business Segment Information

BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

System Energy [Member]

Business Segment Information

BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of March 31, 2022 were Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  See Note 13 to the financial statements in the Form 10-K for discussion of the planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants, including the planned shutdown and sale of Palisades, the only remaining operating plant in Entergy Wholesale Commodities’ merchant nuclear fleet as of March 31, 2022. “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet resulting in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by mid-2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

In addition, Entergy Wholesale Commodities incurred $1 million in the first quarter 2022 and $3 million in the first quarter 2021 of impairment and other related charges associated with these strategic decisions and transactions.

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $5 million in 2022, of which $4 million has been incurred as of March 31, 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

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Risk Management And Fair Values

3 Months Ended

Mar. 31, 2022

Risk Management And Fair Values

RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy Arkansas [Member]

Risk Management And Fair Values

RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy Louisiana [Member]

Risk Management And Fair Values

RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy Mississippi [Member]

Risk Management And Fair Values

RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy New Orleans [Member]

Risk Management And Fair Values

RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy Texas [Member]

Risk Management And Fair Values

RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

System Energy [Member]

Risk Management And Fair Values

RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and

rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for the balance of 2022, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the balance of 2022 is 1.1 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  There were no outstanding derivative contracts held by Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. As of March 31, 2022, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of March 31, 2022 is 2 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of March 31, 2022 is 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2022 is 37,339,100 MMBtu for Entergy, including 14,620,000 MMBtu for Entergy Louisiana and 22,719,100 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of March 31, 2022 is 23,303 GWh for Entergy, including 4,969 GWh for Entergy Arkansas, 10,681 GWh for Entergy Louisiana, 2,529 GWh for Entergy Mississippi, 1,070 GWh for Entergy New Orleans, and 3,959 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of March 31, 2022 and December 31, 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of March 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other

comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the

estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in

April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They were classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities.  For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes.  Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis.  The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects were calculated for this analysis.  This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

XML

Decommissioning Trust Funds

3 Months Ended

Mar. 31, 2022

Decommissioning Trust Funds

DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($175) million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$2,070	$15	$99
2021
Debt Securities	$2,177	$65	$12

The unrealized gains/(losses) above are reported before deferred taxes of ($5) million as of March 31, 2022 and $2 million as of December 31, 2021 for debt securities. The amortized cost of available-for-sale debt securities was $2,153 million as of March 31, 2022 and $2,125 million as of December 31, 2021.  As of March 31, 2022, available-for-sale debt securities had an average coupon rate of approximately 2.77%, an average duration of approximately 6.63 years, and an average maturity of approximately 10.40 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,419	$83	$770	$8
More than 12 months	119	16	99	4
Total	$1,538	$99	$869	$12

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$76	$—
1 year - 5 years	692	473
5 years - 10 years	600	655
10 years - 15 years	150	389
15 years - 20 years	158	130
20 years+	394	530
Total	$2,070	$2,177

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $303 million and $524 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $1 million and $11 million, respectively, and gross losses of $12 million and $11 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of March 31, 2022 and December 31, 2021 was $539 million and $576 million, respectively, for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$509.3	$1.4	$28.3
2021
Debt Securities	$526.3	$11.4	$4.7

The amortized cost of available-for-sale debt securities was $536.2 million as of March 31, 2022 and $519.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.49 years, and an average maturity of approximately 7.74 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($50.5) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$332.9	$21.3	$183.8	$2.9
More than 12 months	55.8	7.0	39.5	1.8
Total	$388.7	$28.3	$223.3	$4.7

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$33.8	$—
1 year - 5 years	153.6	91.7
5 years - 10 years	220.8	217.4
10 years - 15 years	47.9	146.0
15 years - 20 years	27.3	35.7
20 years+	25.9	35.5
Total	$509.3	$526.3

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $7.2 million and $13.8 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.03 million and $0.8 million, respectively, and gross losses of $0.2 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$747.5	$9.7	$30.2
2021
Debt Securities	$794.2	$31.3	$3.3

The amortized cost of available-for-sale debt securities was $767.9 million as of March 31, 2022 and $766.3 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 3.37%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.16 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($70) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$427.4	$25.1	$206.9	$1.4
More than 12 months	41.2	5.1	42.9	1.9
Total	$468.6	$30.2	$249.8	$3.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$29.2	$—
1 year - 5 years	193.9	157.8
5 years - 10 years	170.0	173.0
10 years - 15 years	68.5	123.0
15 years - 20 years	82.9	80.2
20 years+	203.0	260.2
Total	$747.5	$794.2

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $120.5 million and $108.4 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.9 million and $3.3 million, respectively, and gross losses of $5.5 million and $3.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$499.6	$1.9	$27.6
2021
Debt Securities	$524.5	$11.8	$2.9

The amortized cost of available-for-sale debt securities was $525.3 million as of March 31, 2022 and $515.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an

average coupon rate of approximately 2.38%, an average duration of approximately 6.97 years, and an average maturity of approximately 9.87 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($47.7) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

		March 31, 2022		December 31, 2021
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$418.4	$25.5	$276.6	$2.3
More than 12 months		13.3	2.1	11.3	0.6
Total		$431.7	$27.6	$287.9	$2.9

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$6.9	$—
1 year - 5 years	217.3	156.8
5 years - 10 years	136.1	161.8
10 years - 15 years	9.5	58.6
15 years - 20 years	31.1	1.9
20 years+	98.7	145.4
Total	$499.6	$524.5

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $36.2 million and $74.1 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.1 million and $1.2 million, respectively, and gross losses of $0.7 million and $1.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

Entergy estimates the expected credit losses for its available-for-sale securities based on the current credit rating and remaining life of the securities.  To the extent an individual security is determined to be uncollectible, it is written off against this allowance.  Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities.  As of March 31, 2022 and December 31, 2021, Entergy’s allowance for expected credit losses related to available-for-sale securities were $3.2 million and $0.4 million, respectively. Entergy recorded $1.5 million in impairments of available-for-sale debt securities for the three months ended March 31, 2022.

Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021.

Entergy Arkansas [Member]

Decommissioning Trust Funds

DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($175) million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$2,070	$15	$99
2021
Debt Securities	$2,177	$65	$12

The unrealized gains/(losses) above are reported before deferred taxes of ($5) million as of March 31, 2022 and $2 million as of December 31, 2021 for debt securities. The amortized cost of available-for-sale debt securities was $2,153 million as of March 31, 2022 and $2,125 million as of December 31, 2021.  As of March 31, 2022, available-for-sale debt securities had an average coupon rate of approximately 2.77%, an average duration of approximately 6.63 years, and an average maturity of approximately 10.40 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,419	$83	$770	$8
More than 12 months	119	16	99	4
Total	$1,538	$99	$869	$12

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$76	$—
1 year - 5 years	692	473
5 years - 10 years	600	655
10 years - 15 years	150	389
15 years - 20 years	158	130
20 years+	394	530
Total	$2,070	$2,177

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $303 million and $524 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $1 million and $11 million, respectively, and gross losses of $12 million and $11 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of March 31, 2022 and December 31, 2021 was $539 million and $576 million, respectively, for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$509.3	$1.4	$28.3
2021
Debt Securities	$526.3	$11.4	$4.7

The amortized cost of available-for-sale debt securities was $536.2 million as of March 31, 2022 and $519.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.49 years, and an average maturity of approximately 7.74 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($50.5) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$332.9	$21.3	$183.8	$2.9
More than 12 months	55.8	7.0	39.5	1.8
Total	$388.7	$28.3	$223.3	$4.7

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$33.8	$—
1 year - 5 years	153.6	91.7
5 years - 10 years	220.8	217.4
10 years - 15 years	47.9	146.0
15 years - 20 years	27.3	35.7
20 years+	25.9	35.5
Total	$509.3	$526.3

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $7.2 million and $13.8 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.03 million and $0.8 million, respectively, and gross losses of $0.2 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$747.5	$9.7	$30.2
2021
Debt Securities	$794.2	$31.3	$3.3

The amortized cost of available-for-sale debt securities was $767.9 million as of March 31, 2022 and $766.3 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 3.37%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.16 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($70) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$427.4	$25.1	$206.9	$1.4
More than 12 months	41.2	5.1	42.9	1.9
Total	$468.6	$30.2	$249.8	$3.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$29.2	$—
1 year - 5 years	193.9	157.8
5 years - 10 years	170.0	173.0
10 years - 15 years	68.5	123.0
15 years - 20 years	82.9	80.2
20 years+	203.0	260.2
Total	$747.5	$794.2

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $120.5 million and $108.4 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.9 million and $3.3 million, respectively, and gross losses of $5.5 million and $3.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$499.6	$1.9	$27.6
2021
Debt Securities	$524.5	$11.8	$2.9

The amortized cost of available-for-sale debt securities was $525.3 million as of March 31, 2022 and $515.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an

average coupon rate of approximately 2.38%, an average duration of approximately 6.97 years, and an average maturity of approximately 9.87 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($47.7) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

		March 31, 2022		December 31, 2021
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$418.4	$25.5	$276.6	$2.3
More than 12 months		13.3	2.1	11.3	0.6
Total		$431.7	$27.6	$287.9	$2.9

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$6.9	$—
1 year - 5 years	217.3	156.8
5 years - 10 years	136.1	161.8
10 years - 15 years	9.5	58.6
15 years - 20 years	31.1	1.9
20 years+	98.7	145.4
Total	$499.6	$524.5

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $36.2 million and $74.1 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.1 million and $1.2 million, respectively, and gross losses of $0.7 million and $1.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

Entergy estimates the expected credit losses for its available-for-sale securities based on the current credit rating and remaining life of the securities.  To the extent an individual security is determined to be uncollectible, it is written off against this allowance.  Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities.  As of March 31, 2022 and December 31, 2021, Entergy’s allowance for expected credit losses related to available-for-sale securities were $3.2 million and $0.4 million, respectively. Entergy recorded $1.5 million in impairments of available-for-sale debt securities for the three months ended March 31, 2022.

Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021.

Entergy Louisiana [Member]

Decommissioning Trust Funds

DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($175) million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$2,070	$15	$99
2021
Debt Securities	$2,177	$65	$12

The unrealized gains/(losses) above are reported before deferred taxes of ($5) million as of March 31, 2022 and $2 million as of December 31, 2021 for debt securities. The amortized cost of available-for-sale debt securities was $2,153 million as of March 31, 2022 and $2,125 million as of December 31, 2021.  As of March 31, 2022, available-for-sale debt securities had an average coupon rate of approximately 2.77%, an average duration of approximately 6.63 years, and an average maturity of approximately 10.40 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,419	$83	$770	$8
More than 12 months	119	16	99	4
Total	$1,538	$99	$869	$12

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$76	$—
1 year - 5 years	692	473
5 years - 10 years	600	655
10 years - 15 years	150	389
15 years - 20 years	158	130
20 years+	394	530
Total	$2,070	$2,177

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $303 million and $524 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $1 million and $11 million, respectively, and gross losses of $12 million and $11 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of March 31, 2022 and December 31, 2021 was $539 million and $576 million, respectively, for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$509.3	$1.4	$28.3
2021
Debt Securities	$526.3	$11.4	$4.7

The amortized cost of available-for-sale debt securities was $536.2 million as of March 31, 2022 and $519.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.49 years, and an average maturity of approximately 7.74 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($50.5) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$332.9	$21.3	$183.8	$2.9
More than 12 months	55.8	7.0	39.5	1.8
Total	$388.7	$28.3	$223.3	$4.7

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$33.8	$—
1 year - 5 years	153.6	91.7
5 years - 10 years	220.8	217.4
10 years - 15 years	47.9	146.0
15 years - 20 years	27.3	35.7
20 years+	25.9	35.5
Total	$509.3	$526.3

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $7.2 million and $13.8 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.03 million and $0.8 million, respectively, and gross losses of $0.2 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$747.5	$9.7	$30.2
2021
Debt Securities	$794.2	$31.3	$3.3

The amortized cost of available-for-sale debt securities was $767.9 million as of March 31, 2022 and $766.3 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 3.37%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.16 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($70) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$427.4	$25.1	$206.9	$1.4
More than 12 months	41.2	5.1	42.9	1.9
Total	$468.6	$30.2	$249.8	$3.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$29.2	$—
1 year - 5 years	193.9	157.8
5 years - 10 years	170.0	173.0
10 years - 15 years	68.5	123.0
15 years - 20 years	82.9	80.2
20 years+	203.0	260.2
Total	$747.5	$794.2

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $120.5 million and $108.4 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.9 million and $3.3 million, respectively, and gross losses of $5.5 million and $3.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$499.6	$1.9	$27.6
2021
Debt Securities	$524.5	$11.8	$2.9

The amortized cost of available-for-sale debt securities was $525.3 million as of March 31, 2022 and $515.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an

average coupon rate of approximately 2.38%, an average duration of approximately 6.97 years, and an average maturity of approximately 9.87 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($47.7) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

		March 31, 2022		December 31, 2021
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$418.4	$25.5	$276.6	$2.3
More than 12 months		13.3	2.1	11.3	0.6
Total		$431.7	$27.6	$287.9	$2.9

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$6.9	$—
1 year - 5 years	217.3	156.8
5 years - 10 years	136.1	161.8
10 years - 15 years	9.5	58.6
15 years - 20 years	31.1	1.9
20 years+	98.7	145.4
Total	$499.6	$524.5

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $36.2 million and $74.1 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.1 million and $1.2 million, respectively, and gross losses of $0.7 million and $1.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

Entergy estimates the expected credit losses for its available-for-sale securities based on the current credit rating and remaining life of the securities.  To the extent an individual security is determined to be uncollectible, it is written off against this allowance.  Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities.  As of March 31, 2022 and December 31, 2021, Entergy’s allowance for expected credit losses related to available-for-sale securities were $3.2 million and $0.4 million, respectively. Entergy recorded $1.5 million in impairments of available-for-sale debt securities for the three months ended March 31, 2022.

Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021.

System Energy [Member]

Decommissioning Trust Funds

DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($175) million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$2,070	$15	$99
2021
Debt Securities	$2,177	$65	$12

The unrealized gains/(losses) above are reported before deferred taxes of ($5) million as of March 31, 2022 and $2 million as of December 31, 2021 for debt securities. The amortized cost of available-for-sale debt securities was $2,153 million as of March 31, 2022 and $2,125 million as of December 31, 2021.  As of March 31, 2022, available-for-sale debt securities had an average coupon rate of approximately 2.77%, an average duration of approximately 6.63 years, and an average maturity of approximately 10.40 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,419	$83	$770	$8
More than 12 months	119	16	99	4
Total	$1,538	$99	$869	$12

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$76	$—
1 year - 5 years	692	473
5 years - 10 years	600	655
10 years - 15 years	150	389
15 years - 20 years	158	130
20 years+	394	530
Total	$2,070	$2,177

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $303 million and $524 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $1 million and $11 million, respectively, and gross losses of $12 million and $11 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of March 31, 2022 and December 31, 2021 was $539 million and $576 million, respectively, for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$509.3	$1.4	$28.3
2021
Debt Securities	$526.3	$11.4	$4.7

The amortized cost of available-for-sale debt securities was $536.2 million as of March 31, 2022 and $519.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.49 years, and an average maturity of approximately 7.74 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($50.5) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$332.9	$21.3	$183.8	$2.9
More than 12 months	55.8	7.0	39.5	1.8
Total	$388.7	$28.3	$223.3	$4.7

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$33.8	$—
1 year - 5 years	153.6	91.7
5 years - 10 years	220.8	217.4
10 years - 15 years	47.9	146.0
15 years - 20 years	27.3	35.7
20 years+	25.9	35.5
Total	$509.3	$526.3

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $7.2 million and $13.8 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.03 million and $0.8 million, respectively, and gross losses of $0.2 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$747.5	$9.7	$30.2
2021
Debt Securities	$794.2	$31.3	$3.3

The amortized cost of available-for-sale debt securities was $767.9 million as of March 31, 2022 and $766.3 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an average coupon rate of approximately 3.37%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.16 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($70) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$427.4	$25.1	$206.9	$1.4
More than 12 months	41.2	5.1	42.9	1.9
Total	$468.6	$30.2	$249.8	$3.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$29.2	$—
1 year - 5 years	193.9	157.8
5 years - 10 years	170.0	173.0
10 years - 15 years	68.5	123.0
15 years - 20 years	82.9	80.2
20 years+	203.0	260.2
Total	$747.5	$794.2

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $120.5 million and $108.4 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.9 million and $3.3 million, respectively, and gross losses of $5.5 million and $3.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$499.6	$1.9	$27.6
2021
Debt Securities	$524.5	$11.8	$2.9

The amortized cost of available-for-sale debt securities was $525.3 million as of March 31, 2022 and $515.6 million as of December 31, 2021.  As of March 31, 2022, the available-for-sale debt securities had an

average coupon rate of approximately 2.38%, an average duration of approximately 6.97 years, and an average maturity of approximately 9.87 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2022 on equity securities still held as of March 31, 2022 were ($47.7) million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

		March 31, 2022		December 31, 2021
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$418.4	$25.5	$276.6	$2.3
More than 12 months		13.3	2.1	11.3	0.6
Total		$431.7	$27.6	$287.9	$2.9

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$6.9	$—
1 year - 5 years	217.3	156.8
5 years - 10 years	136.1	161.8
10 years - 15 years	9.5	58.6
15 years - 20 years	31.1	1.9
20 years+	98.7	145.4
Total	$499.6	$524.5

During the three months ended March 31, 2022 and 2021, proceeds from the dispositions of available-for-sale securities amounted to $36.2 million and $74.1 million, respectively.  During the three months ended March 31, 2022 and 2021, gross gains of $0.1 million and $1.2 million, respectively, and gross losses of $0.7 million and $1.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

Entergy estimates the expected credit losses for its available-for-sale securities based on the current credit rating and remaining life of the securities.  To the extent an individual security is determined to be uncollectible, it is written off against this allowance.  Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities.  As of March 31, 2022 and December 31, 2021, Entergy’s allowance for expected credit losses related to available-for-sale securities were $3.2 million and $0.4 million, respectively. Entergy recorded $1.5 million in impairments of available-for-sale debt securities for the three months ended March 31, 2022.

Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021.

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Income Taxes

3 Months Ended

Mar. 31, 2022

Income Taxes

INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy Arkansas [Member]

Income Taxes

INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy Louisiana [Member]

Income Taxes

INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy Mississippi [Member]

Income Taxes

INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy New Orleans [Member]

Income Taxes

INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy Texas [Member]

Income Taxes

INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

System Energy [Member]

Income Taxes

INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

XML

Property, Plant, And Equipment

3 Months Ended

Mar. 31, 2022

Property, Plant, And Equipment

PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

Entergy Arkansas [Member]

Property, Plant, And Equipment

PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

Entergy Louisiana [Member]

Property, Plant, And Equipment

PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

Entergy Mississippi [Member]

Property, Plant, And Equipment

PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

Entergy New Orleans [Member]

Property, Plant, And Equipment

PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

Entergy Texas [Member]

Property, Plant, And Equipment

PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

System Energy [Member]

Property, Plant, And Equipment

PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at March 31, 2022 were $402 million for Entergy, $33.5 million for Entergy Arkansas, $239.7 million for Entergy Louisiana, $13.8 million for Entergy Mississippi, $4 million for Entergy New Orleans, $35.1 million for Entergy Texas, and $34.5 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2021 were $723 million for Entergy, $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

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Variable Interest Entities

3 Months Ended

Mar. 31, 2022

Variable Interest Entities

VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

Entergy Arkansas [Member]

Variable Interest Entities

VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

Entergy Louisiana [Member]

Variable Interest Entities

VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

Entergy Mississippi [Member]

Variable Interest Entities

VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

Entergy New Orleans [Member]

Variable Interest Entities

VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

Entergy Texas [Member]

Variable Interest Entities

VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

System Energy [Member]

Variable Interest Entities

VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the three months ended March 31, 2022 and the three months ended March 31, 2021.

AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements in the Form 10-K for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar Facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements in the Form 10-K for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of March 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $142 million, primarily consisting of property, plant, and equipment and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113 million.

XML

Revenue Recognition

3 Months Ended

Mar. 31, 2022

Revenue Recognition

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

Entergy Arkansas [Member]

Revenue Recognition

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

Entergy Louisiana [Member]

Revenue Recognition

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

Entergy Mississippi [Member]

Revenue Recognition

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

Entergy New Orleans [Member]

Revenue Recognition

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

Entergy Texas [Member]

Revenue Recognition

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

System Energy [Member]

Revenue Recognition

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, there were increases in customer write-offs beginning in second quarter 2021 primarily resulting from the effects of the COVID-19 pandemic. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

XML

Equity (Tables)

3 Months Ended

Mar. 31, 2022

Schedule Of Earnings Per Share Basic And Diluted

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:

	For the Three Months Ended March 31,
	2022			2021
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$276.4	202.9	$1.36	$334.6	200.5	$1.67
Average dilutive effect of:
Stock options		0.5	—		0.4	(0.01)
Other equity plans		0.4	—		0.2	—
Equity forwards		0.1	—		—	—
Diluted earnings per share	$276.4	203.9	$1.36	$334.6	201.1	$1.66

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.9 million for the three months ended March 31, 2022 and approximately 1 million for the three months ended March 31, 2021.

Schedule of Accumulated Other Comprehensive Income (Loss)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2022 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2022	($1,035)	($338,647)	$7,154	($332,528)
Other comprehensive income (loss) before reclassifications	(14)	—	(15,875)	(15,889)
Amounts reclassified from accumulated other comprehensive income (loss)	38	8,328	3,473	11,839
Net other comprehensive income (loss) for the period	24	8,328	(12,402)	(4,050)
Ending balance, March 31, 2022	($1,011)	($330,319)	($5,248)	($336,578)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2021 by component:

	Cash flow hedges net unrealized gain (loss)	Pension and other postretirement liabilities	Net unrealized investment gain (loss)	Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, January 1, 2021	$28,719	($534,576)	$56,650	($449,207)
Other comprehensive income (loss) before reclassifications	1,482	—	(45,301)	(43,819)
Amounts reclassified from accumulated other comprehensive income (loss)	(31,062)	22,967	614	(7,481)
Net other comprehensive income (loss) for the period	(29,580)	22,967	(44,687)	(51,300)
Ending balance, March 31, 2021	($861)	($511,609)	$11,963	($500,507)

Reclassification out of Accumulated Other Comprehensive Income

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$—	$39,367	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	(48)	39,319
Income taxes	10	(8,257)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	($38)	$31,062
Pension and other postretirement liabilities
Amortization of prior-service credit	$3,837	$5,248	(a)
Amortization of loss	(13,925)	(34,529)	(a)
Settlement loss	(782)	—	(a)
Total amortization	(10,870)	(29,281)
Income taxes	2,542	6,314	Income taxes
Total amortization (net of tax)	($8,328)	($22,967)
Net unrealized investment gain (loss)
Realized gain (loss)	($5,495)	($972)	Interest and investment income
Income taxes	2,022	358	Income taxes
Total realized investment gain (loss) (net of tax)	($3,473)	($614)
Total reclassifications for the period (net of tax)	($11,839)	$7,481

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Entergy Louisiana [Member]

Schedule of Accumulated Other Comprehensive Income (Loss)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2022 and 2021:

	Pension and Other Postretirement Liabilities
	2022	2021
	(In Thousands)
Beginning balance, January 1,	$8,278	$4,327
Amounts reclassified from accumulated other comprehensive income (loss)	(613)	(407)
Net other comprehensive income (loss) for the period	(613)	(407)
Ending balance, March 31,	$7,665	$3,920

Reclassification out of Accumulated Other Comprehensive Income

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2022 and 2021 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2022	2021
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,158	$1,230	(a)
Amortization of loss	(319)	(679)	(a)
Total amortization	839	551
Income taxes	(226)	(144)	Income taxes
Total amortization (net of tax)	613	407
Total reclassifications for the period (net of tax)	$613	$407

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2022

Summary Of The Borrowings Outstanding And Capacity Available Under The Facility

As of March 31, 2022, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$150	$3	$3,347

Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]

Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

Short-Term Borrowings And The Outstanding Short-Term Borrowings

The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel

To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

Notes Payable By Variable Interest Entities

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

Book Value And The Fair Value Of Long-Term Debt

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Arkansas [Member]

Summary Of The Borrowings Outstanding And Capacity Available Under The Facility

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]

Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

Short-Term Borrowings And The Outstanding Short-Term Borrowings

The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel

To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

Notes Payable By Variable Interest Entities

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

Book Value And The Fair Value Of Long-Term Debt

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Louisiana [Member]

Summary Of The Borrowings Outstanding And Capacity Available Under The Facility

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]

Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

Short-Term Borrowings And The Outstanding Short-Term Borrowings

The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel

To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

Notes Payable By Variable Interest Entities

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

Book Value And The Fair Value Of Long-Term Debt

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Mississippi [Member]

Summary Of The Borrowings Outstanding And Capacity Available Under The Facility

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]

Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

Short-Term Borrowings And The Outstanding Short-Term Borrowings

The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Book Value And The Fair Value Of Long-Term Debt

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy New Orleans [Member]

Summary Of The Borrowings Outstanding And Capacity Available Under The Facility

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]

Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

Short-Term Borrowings And The Outstanding Short-Term Borrowings

The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Book Value And The Fair Value Of Long-Term Debt

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Entergy Texas [Member]

Summary Of The Borrowings Outstanding And Capacity Available Under The Facility

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2022 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2022	Letters of Credit Outstanding as of March 31, 2022
Entergy Arkansas	April 2022 (e)	$25 million (b)	3.00%	$—	$—
Entergy Arkansas	June 2026	$150 million (c)	1.58%	$—	$—
Entergy Louisiana	June 2026	$350 million (c)	1.71%	$—	$—
Entergy Mississippi	April 2022 (f)	$37.5 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$35 million (d)	1.96%	$—	$—
Entergy Mississippi	April 2022 (f)	$10 million (d)	1.96%	$—	$—
Entergy New Orleans	June 2024	$25 million (c)	2.08%	$—	$—
Entergy Texas	June 2026	$150 million (c)	1.71%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2022 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(e)In April 2022, Entergy Arkansas extended the expiration of the credit facility to July 2022.

(f)In April 2022, Entergy Mississippi renewed its three existing short-term credit facilities, increased the aggregate amount available under the facilities to $95 million, and extended the expiration date of each credit facility to April 2023. Also in April 2022, Entergy Mississippi entered into a long-term credit facility in the amount of $150 million with an expiration date of July 2024. The interest rates for these facilities will be based on the Secured Overnight Financing Rate.

Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]

Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2022:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of March 31, 2022 (a) (b)
Entergy Arkansas	$25 million	0.78%	$7.5 million
Entergy Louisiana	$125 million	0.78%	$11.0 million
Entergy Mississippi	$65 million	0.78%	$2.3 million
Entergy New Orleans	$15 million	1.00%	$1.0 million
Entergy Texas	$80 million	0.875%	$79.6 million

(a)As of March 31, 2022, letters of credit posted with MISO covered financial transmission right exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2022, in addition to the $2.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

Short-Term Borrowings And The Outstanding Short-Term Borrowings

The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Book Value And The Fair Value Of Long-Term Debt

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

System Energy [Member]

Short-Term Borrowings And The Outstanding Short-Term Borrowings

The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$22
Entergy New Orleans	$150	$—
Entergy Texas	$200	$171
System Energy	$200	$—

Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel

To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2022:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2022
		(Dollars in Millions)
Entergy Arkansas VIE	June 2024	$80	1.10%	$—
Entergy Louisiana River Bend VIE	June 2024	$105	1.14%	$30.8
Entergy Louisiana Waterford VIE	June 2024	$105	1.15%	$82.1
System Energy VIE	June 2024	$120	1.17%	$100

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

Notes Payable By Variable Interest Entities

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2022 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 million
Entergy Arkansas VIE	1.84% Series N due July 2026	$90 million
Entergy Louisiana River Bend VIE	2.51% Series V due June 2027	$70 million
Entergy Louisiana Waterford VIE	3.22% Series I due December 2023	$20 million
System Energy VIE	2.05% Series K due September 2027	$90 million

Book Value And The Fair Value Of Long-Term Debt

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2022 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$27,215,784	$26,731,277
Entergy Arkansas	$4,163,602	$4,101,516
Entergy Louisiana	$12,022,131	$11,959,123
Entergy Mississippi	$2,180,197	$2,152,275
Entergy New Orleans	$788,501	$775,566
Entergy Texas	$2,325,371	$2,254,487
System Energy	$805,353	$769,552

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$25,880,901	$27,061,171
Entergy Arkansas	$3,958,862	$4,176,577
Entergy Louisiana	$10,914,346	$11,492,650
Entergy Mississippi	$2,179,989	$2,346,230
Entergy New Orleans	$788,165	$765,538
Entergy Texas	$2,354,148	$2,483,995
System Energy	$741,296	$743,040

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

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Stock-Based Compensation (Tables) - Entergy Corporation [Member]

3 Months Ended

Mar. 31, 2022

Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]

Financial Information For Stock Options

The following table includes financial information for outstanding stock options for the three months ended March 31, 2022 and 2021:

	2022	2021
	(In Millions)
Compensation expense included in Entergy’s consolidated net income	$1.1	$1.0
Tax benefit recognized in Entergy’s consolidated net income	$0.3	$0.3
Compensation cost capitalized as part of fixed assets and materials and supplies	$0.4	$0.4

Financial Information For Restricted Stock

The following table includes financial information for other outstanding equity awards for the three months ended March 31, 2022 and 2021:

	2022	2021
	(In Millions)
Compensation expense included in Entergy’s consolidated net income	$11.4	$10.8
Tax benefit recognized in Entergy’s consolidated net income	$2.9	$2.7
Compensation cost capitalized as part of fixed assets and materials and supplies	$4.4	$4.0

XML

Retirement And Other Postretirement Benefits (Tables)

3 Months Ended

Mar. 31, 2022

Defined Benefit Plan Disclosure [Line Items]

Reclassification out of Accumulated Other Comprehensive Income, amortization

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$37,660	$45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of net loss	60,579	104,392
Net pension costs	$45,751	$90,019

Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

Entergy’s other postretirement benefit income, including amounts capitalized, for the first quarters of 2022 and 2021, included the following components:

	2022	2021
	(In Thousands)
Service cost - benefits earned during the period	$6,184	$6,645
Interest cost on accumulated postretirement benefit obligation (APBO)	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service credit	(6,388)	(8,267)
Amortization of net loss	1,083	713
Net other postretirement benefit income	($3,149)	($6,394)

Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Arkansas [Member] | Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Entergy Arkansas [Member] | Non Qualified Pension Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Entergy Louisiana [Member]

Defined Benefit Plan Disclosure [Line Items]

Reclassification out of Accumulated Other Comprehensive Income, amortization

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2022 and 2021:

2022	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$4,014	($177)	$3,837
Amortization of net loss	(12,910)	(596)	(419)	(13,925)
Settlement loss	—	—	(782)	(782)
	($12,910)	$3,418	($1,378)	($10,870)
Entergy Louisiana
Amortization of prior service credit	$—	$1,158	$—	$1,158
Amortization of net gain (loss)	(504)	186	(1)	(319)
	($504)	$1,344	($1)	$839

2021	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$5,288	($40)	$5,248
Amortization of net loss	(33,439)	(495)	(595)	(34,529)
	($33,439)	$4,793	($635)	($29,281)
Entergy Louisiana
Amortization of prior service credit	$—	$1,230	$—	$1,230
Amortization of net gain (loss)	(769)	91	(1)	(679)
	($769)	$1,321	($1)	$551

Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Louisiana [Member] | Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Entergy Louisiana [Member] | Non Qualified Pension Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Entergy Mississippi [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Mississippi [Member] | Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Entergy Mississippi [Member] | Non Qualified Pension Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Entergy New Orleans [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy New Orleans [Member] | Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Entergy New Orleans [Member] | Non Qualified Pension Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

Entergy Texas [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

Entergy Texas [Member] | Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

Entergy Texas [Member] | Non Qualified Pension Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for first quarters of 2022 and 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2022	$72	$27	$80	$29	$215
2021	$90	$44	$96	$8	$115

Reflected in Entergy Texas’ non-qualified pension costs in the first quarter of 2022 were settlement charges of $119 thousand related to the payment of lump sum benefits out of the plan.

System Energy [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,858	$9,137	$2,130	$752	$1,632	$2,045
Interest cost on projected benefit obligation	9,317	10,499	2,678	1,139	2,175	2,338
Expected return on assets	(19,247)	(21,133)	(5,203)	(2,515)	(4,937)	(4,623)
Amortization of net loss	13,426	12,597	3,810	1,368	2,555	3,266
Net pension cost	$10,354	$11,100	$3,415	$744	$1,425	$3,026

2021	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$7,418	$10,043	$2,364	$796	$1,801	$2,314
Interest cost on projected benefit obligation	8,341	9,562	2,462	1,029	1,949	2,142
Expected return on assets	(19,670)	(22,538)	(5,587)	(2,622)	(5,237)	(4,778)
Amortization of net loss	19,303	19,204	5,668	2,270	3,711	5,326
Net pension cost	$15,392	$16,271	$4,907	$1,473	$2,224	$5,004

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2022:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2022 pension contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Pension contributions made through March 2022	$15,096	$10,241	$2,972	$922	$1,340	$3,996
Remaining estimated pension contributions to be made in 2022	$25,744	$12,676	$9,880	$—	$584	$8,764

System Energy [Member] | Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2022 and 2021, included the following components:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,114	$1,408	$339	$99	$331	$310
Interest cost on APBO	1,263	1,443	350	174	399	279
Expected return on assets	(4,483)	—	(1,394)	(1,499)	(2,568)	(791)
Amortization of prior service credit	471	(1,158)	(443)	(229)	(1,093)	(80)
Amortization of net (gain) loss	218	(186)	56	(225)	162	30
Net other postretirement benefit cost (income)	($1,417)	$1,507	($1,092)	($1,680)	($2,769)	($252)

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$1,034	$1,544	$362	$109	$346	$335
Interest cost on APBO	932	1,130	278	130	317	220
Expected return on assets	(4,505)	—	(1,384)	(1,438)	(2,548)	(789)
Amortization of prior service credit	(280)	(1,230)	(444)	(229)	(936)	(109)
Amortization of net (gain) loss	49	(91)	19	(178)	100	15
Net other postretirement benefit cost (income)	($2,770)	$1,353	($1,169)	($1,606)	($2,721)	($328)

XML

Business Segment Information (Tables) - Entergy Corporation [Member]

3 Months Ended

Mar. 31, 2022

Segment Financial Information

Entergy’s segment financial information for the first quarters of 2022 and 2021 were as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
2022
Operating revenues	$2,728,156	$149,777	$—	($8)	$2,877,925
Income taxes	$75,359	$2,854	($11,716)	$—	$66,497
Consolidated net income (loss)	$343,156	$7,859	($39,476)	($31,946)	$279,593
Total assets as of March 31, 2022	$61,684,609	$1,137,843	$601,479	($3,590,405)	$59,833,526
2021
Operating revenues	$2,596,616	$248,219	$23	($20)	$2,844,838
Income taxes	$59,734	$15,560	($9,352)	$—	$65,942
Consolidated net income (loss)	$360,600	$38,124	($27,680)	($31,899)	$339,145
Total assets as of December 31, 2021	$59,733,625	$1,242,675	$561,168	($2,083,226)	$59,454,242

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

Restructuring and Related Costs [Table Text Block]

Total restructuring charges for the first quarters of 2022 and 2021 were comprised of the following:

	2022			2021
	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total	Employee retention and severance expenses and other benefits-related costs	Contracted economic development costs	Total
	(In Millions)
Balance as of January 1,	$37	$—	$37	$145	$14	$159
Restructuring costs accrued	4	—	4	13	—	13
Cash paid out	—	—	—	1	—	1
Balance as of March 31,	$41	$—	$41	$157	$14	$171

XML

Risk Management And Fair Values (Tables)

3 Months Ended

Mar. 31, 2022

Fair Values Of Derivative Instruments

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2022 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$54	$—	$54	Utility
Natural gas swaps and options	Other deferred debits and other assets	$8	$—	$8	Utility
Financial transmission rights	Prepayments and other	$2	($1)	$1	Utility and Entergy Wholesale Commodities

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 are shown in the table below.  

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Business
		(In Millions)
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other	$6	$—	$6	Utility
Natural gas swaps and options	Other deferred debits and other assets	$5	$—	$5	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities	$7	$—	$7	Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $8 million posted as of March 31, 2022 and $8 million posted as of December 31, 2021. Also excludes letters of credit in the amount of $1 million posted as of March 31, 2022.

Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income

As discussed above, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2021 were as follows:

Instrument	Amount of gain (loss) recognized in other comprehensive income	Income Statement location	Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
	(In Millions)		(In Millions)
Electricity swaps and options	$2	Competitive businesses operating revenues	$39

(a)Before taxes of $8 million for the three months ended March 31, 2021

Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$55
Financial transmission rights	Purchased power	(b)	$23
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the Entergy Wholesale Commodities portfolio of derivative instruments in April 2021.

Assets and liabilities at fair value on a recurring basis

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$625	$—	$—	$625
Decommissioning trust funds (a):
Equity securities	103	—	—	103
Debt securities (b)	736	1,334	—	2,070
Common trusts (c)				3,040
Securitization recovery trust account	15	—	—	15
Escrow accounts	49	—	—	49
Gas hedge contracts	54	8	—	62
Financial transmission rights	—	—	1	1
	$1,582	$1,342	$1	$5,965

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$398	$—	$—	$398
Decommissioning trust funds (a):
Equity securities	132	—	—	132
Debt securities (b)	770	1,407	—	2,177
Common trusts (c)				3,205
Securitization recovery trust account	29	—	—	29
Escrow accounts	49	—	—	49
Gas hedge contracts	6	5	—	11
Financial transmission rights	—	—	4	4
	$1,384	$1,412	$4	$6,005
Liabilities:
Gas hedge contracts	$7	$—	$—	$7

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $3.2 million as of March 31, 2022 and $0.4 million as

of December 31, 2021 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022 and 2021:

	2022	2021
	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$4	$38	$9
Total gains (losses) for the period (a)
Included in earnings	—	(2)	4
Included in other comprehensive income	—	2	—
Included as a regulatory liability/asset	20	—	119
Settlements	(23)	(38)	(128)
Balance as of March 31,	$1	$—	$4

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $0.7 million for the three months ended March 31, 2021.

Entergy Arkansas [Member]

Fair Values Of Derivative Instruments

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Assets and liabilities at fair value on a recurring basis

Entergy Arkansas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$107.2	$—	$—	$107.2
Decommissioning trust funds (a):
Equity securities	2.7	—	—	2.7
Debt securities	132.4	376.9	—	509.3
Common trusts (b)				848.6
Financial transmission rights	—	—	0.4	0.4
	$242.3	$376.9	$0.4	$1,468.2

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$4.8	$—	$—	$4.8
Decommissioning trust funds (a):
Equity securities	16.7	—	—	16.7
Debt securities	119.5	406.8	—	526.3
Common trusts (b)				895.4
Financial transmission rights	—	—	2.3	2.3
	$141.0	$406.8	$2.3	$1,445.5

Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy Louisiana [Member]

Fair Values Of Derivative Instruments

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Assets and liabilities at fair value on a recurring basis

Entergy Louisiana

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$140.7	$—	$—	$140.7
Decommissioning trust funds (a):
Equity securities	22.8	—	—	22.8
Debt securities	230.0	517.5	—	747.5
Common trusts (b)				1,235.1
Gas hedge contracts	19.3	8.3	—	27.6
Financial transmission rights	—	—	0.3	0.3
	$412.8	$525.8	$0.3	$2,174.0

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2
Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5

Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy Mississippi [Member]

Fair Values Of Derivative Instruments

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Assets and liabilities at fair value on a recurring basis

Entergy Mississippi

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$48.9	$—	$—	$48.9
Gas hedge contracts	35.0	—	—	35.0
Financial transmission rights	—	—	0.2	0.2
	$83.9	$—	$0.2	$84.1

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7

Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy New Orleans [Member]

Fair Values Of Derivative Instruments

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Assets and liabilities at fair value on a recurring basis

Entergy New Orleans

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$31.1	$—	$—	$31.1
Securitization recovery trust account	5.1	—	—	5.1
Financial transmission rights	—	—	0.1	0.1
	$36.2	$—	$0.1	$36.3

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$42.8	$—	$—	$42.8
Securitization recovery trust account	2.0	—	—	2.0
Financial transmission rights	—	—	0.1	0.1
	$44.8	$—	$0.1	$44.9
Liabilities:
Gas hedge contracts	$0.5	$—	$—	$0.5

Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

Entergy Texas [Member]

Fair Values Of Derivative Instruments

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$19.3	$—	$19.3	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$8.3	$—	$8.3	Entergy Louisiana
Natural gas swaps	Prepayments and other	$35.0	$—	$35.0	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.6	($0.2)	$0.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.2	$—	$0.2	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.5	$—	$0.5	Entergy Texas

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 were as follows:

Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas
Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of March 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.4 million for Entergy Mississippi. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2022 and 2021 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2022
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$11.1	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$42.8	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$1.1	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$7.5	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$1.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$0.8	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$3.8	(b)	Entergy Texas
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	$1.8	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$5.2	(a)	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($0.1)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power	$77.9	(b)	Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Assets and liabilities at fair value on a recurring basis

Entergy Texas

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$10.0	$—	$—	$10.0
Financial transmission rights	—	—	0.5	0.5
	$10.0	$—	$0.5	$10.5

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$26.6	$—	$—	$26.6
Financial transmission rights	—	—	0.8	0.8
	$26.6	$—	$0.8	$27.4

Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2022.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.3	$0.6	$0.3	$0.1	$0.8
Gains (losses) included as a regulatory liability/asset	5.6	9.1	0.9	0.8	3.5
Settlements	(7.5)	(9.4)	(1.0)	(0.8)	(3.8)
Balance as of March 31,	$0.4	$0.3	$0.2	$0.1	$0.5

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2021.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$2.7	$4.2	$0.6	$0.1	$1.6
Gains (losses) included as a regulatory liability/asset	24.8	9.3	6.9	1.2	76.8
Settlements	(26.1)	(12.3)	(7.2)	(1.2)	(77.9)
Balance as of March 31,	$1.4	$1.2	$0.3	$0.1	$0.5

System Energy [Member]

Assets and liabilities at fair value on a recurring basis

System Energy

2022	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$98.2	$—	$—	$98.2
Decommissioning trust funds (a):
Equity securities	4.9	—	—	4.9
Debt Securities	251.5	248.1	—	499.6
Common trusts (b)				803.7
	$354.6	$248.1	$—	$1,406.4

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$89.1	$—	$—	$89.1
Decommissioning trust funds (a):
Equity securities	12.9	—	—	12.9
Debt securities	273.0	251.5	—	524.5
Common trusts (b)				847.9
	$375.0	$251.5	$—	$1,474.4

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Decommissioning Trust Funds (Tables)

3 Months Ended

Mar. 31, 2022

Securities Held

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$2,070	$15	$99
2021
Debt Securities	$2,177	$65	$12

Available For Sale Securities Continuous Unrealized Loss Position Fair Value

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,419	$83	$770	$8
More than 12 months	119	16	99	4
Total	$1,538	$99	$869	$12

Fair Value Of Debt Securities By Contractual Maturities

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$76	$—
1 year - 5 years	692	473
5 years - 10 years	600	655
10 years - 15 years	150	389
15 years - 20 years	158	130
20 years+	394	530
Total	$2,070	$2,177

Entergy Arkansas [Member]

Securities Held

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$509.3	$1.4	$28.3
2021
Debt Securities	$526.3	$11.4	$4.7

Available For Sale Securities Continuous Unrealized Loss Position Fair Value

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$332.9	$21.3	$183.8	$2.9
More than 12 months	55.8	7.0	39.5	1.8
Total	$388.7	$28.3	$223.3	$4.7

Fair Value Of Debt Securities By Contractual Maturities

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$33.8	$—
1 year - 5 years	153.6	91.7
5 years - 10 years	220.8	217.4
10 years - 15 years	47.9	146.0
15 years - 20 years	27.3	35.7
20 years+	25.9	35.5
Total	$509.3	$526.3

Entergy Louisiana [Member]

Securities Held

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$747.5	$9.7	$30.2
2021
Debt Securities	$794.2	$31.3	$3.3

Available For Sale Securities Continuous Unrealized Loss Position Fair Value

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

	March 31, 2022		December 31, 2021
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$427.4	$25.1	$206.9	$1.4
More than 12 months	41.2	5.1	42.9	1.9
Total	$468.6	$30.2	$249.8	$3.3

Fair Value Of Debt Securities By Contractual Maturities

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$29.2	$—
1 year - 5 years	193.9	157.8
5 years - 10 years	170.0	173.0
10 years - 15 years	68.5	123.0
15 years - 20 years	82.9	80.2
20 years+	203.0	260.2
Total	$747.5	$794.2

System Energy [Member]

Securities Held

The available-for-sale securities held as of March 31, 2022 and December 31, 2021 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2022
Debt Securities	$499.6	$1.9	$27.6
2021
Debt Securities	$524.5	$11.8	$2.9

Available For Sale Securities Continuous Unrealized Loss Position Fair Value

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of March 31, 2022 and December 31, 2021:

		March 31, 2022		December 31, 2021
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$418.4	$25.5	$276.6	$2.3
More than 12 months		13.3	2.1	11.3	0.6
Total		$431.7	$27.6	$287.9	$2.9

Fair Value Of Debt Securities By Contractual Maturities

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2022 and December 31, 2021 were as follows:

	2022	2021
	(In Millions)
Less than 1 year	$6.9	$—
1 year - 5 years	217.3	156.8
5 years - 10 years	136.1	161.8
10 years - 15 years	9.5	58.6
15 years - 20 years	31.1	1.9
20 years+	98.7	145.4
Total	$499.6	$524.5

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Income Taxes Income Taxes (Tables)

3 Months Ended

Mar. 31, 2022

Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy Arkansas [Member]

Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy Louisiana [Member]

Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy New Orleans [Member]

Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

Entergy Texas [Member]

Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

System Energy [Member]

Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended March 31,
	2022	2021
	(In Millions)
Entergy	$17	$41
Entergy Arkansas	$—	$8
Entergy Louisiana	$9	$8
Entergy New Orleans	$1	$—
Entergy Texas	$7	$7
System Energy	$—	$18

XML

Revenue Recognition Revenue Recognition (Tables)

3 Months Ended

Mar. 31, 2022

Disaggregation of Revenue [Table Text Block]

Entergy’s total revenues for the three months ended March 31, 2022 and 2021 were as follows:

	2022	2021
	(In Thousands)
Utility:
Residential	$986,023	$966,855
Commercial	634,626	572,676
Industrial	743,634	597,652
Governmental	57,292	56,798
Total billed retail	2,421,575	2,193,981
Sales for resale (a)	128,959	205,075
Other electric revenues (b)	93,880	80,261
Revenues from contracts with customers	2,644,414	2,479,317
Other revenues (c)	11,362	59,103
Total electric revenues	2,655,776	2,538,420
Natural gas	72,361	58,168
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	144,823	232,113
Other revenues (c)	4,965	16,137
Total competitive businesses revenues	149,788	248,250
Total operating revenues	$2,877,925	$2,844,838

r 30, 2021 and 2020 were as follows:

Allowance for Doubtful Accounts

The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

Entergy Arkansas [Member]

Disaggregation of Revenue [Table Text Block]

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for Doubtful Accounts

The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

Entergy Louisiana [Member]

Disaggregation of Revenue [Table Text Block]

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for Doubtful Accounts

The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

Entergy Mississippi [Member]

Disaggregation of Revenue [Table Text Block]

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for Doubtful Accounts

The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

Entergy New Orleans [Member]

Disaggregation of Revenue [Table Text Block]

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for Doubtful Accounts

The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

Entergy Texas [Member]

Disaggregation of Revenue [Table Text Block]

The Utility operating companies’ total revenues for the three months ended March 31, 2022 and 2021 were as follows:

2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$227,786	$353,567	$152,939	$58,658	$193,073
Commercial	113,238	257,591	110,661	45,572	107,564
Industrial	109,675	451,954	39,157	6,272	136,576
Governmental	4,460	19,016	12,000	15,033	6,783
Total billed retail	455,159	1,082,128	314,757	125,535	443,996
Sales for resale (a)	70,414	107,701	21,641	26,540	17,644
Other electric revenues (b)	30,572	41,482	10,337	1,393	11,449
Revenues from contracts with customers	556,145	1,231,311	346,735	153,468	473,089
Other revenues (c)	2,811	5,926	2,294	1,178	(607)
Total electric revenues	558,956	1,237,237	349,029	154,646	472,482
Natural gas	—	28,735	—	43,626	—
Total operating revenues	$558,956	$1,265,972	$349,029	$198,272	$472,482

2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$237,182	$335,760	$147,636	$66,427	$179,850
Commercial	106,416	224,649	97,936	47,799	95,876
Industrial	103,412	347,009	33,980	6,789	106,462
Governmental	4,256	18,616	10,543	16,380	7,003
Total billed retail	451,266	926,034	290,095	137,395	389,191
Sales for resale (a)	110,085	80,428	40,311	4,696	74,073
Other electric revenues (b)	19,583	43,910	3,950	(3,359)	17,529
Revenues from contracts with customers	580,934	1,050,372	334,356	138,732	480,793
Other revenues (c)	2,452	29,291	2,263	416	(573)
Total electric revenues	583,386	1,079,663	336,619	139,148	480,220
Natural gas	—	27,981	—	30,187	—
Total operating revenues	$583,386	$1,107,644	$336,619	$169,335	$480,220

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for Doubtful Accounts

The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2022 and 2021.

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2021	$68.6	$13.1	$29.2	$7.2	$13.3	$5.8
Provisions	(5.9)	3.7	(6.1)	(0.9)	(2.4)	(0.2)
Write-offs	(45.3)	(14.4)	(17.5)	(4.1)	(5.4)	(3.9)
Recoveries	14.1	4.1	5.5	1.2	2.2	1.1
Balance as of March 31, 2022	$31.5	$6.5	$11.1	$3.4	$7.7	$2.8

	Entergy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2020	$117.7	$18.3	$45.7	$19.5	$17.4	$16.8
Provisions	3.2	2.4	2.3	(2.2)	1.8	(1.1)
Write-offs	(3.8)	(0.1)	(2.1)	(0.8)	—	(0.8)
Recoveries	1.9	0.6	0.7	0.3	0.2	0.1
Balance as of March 31, 2021	$119.0	$21.2	$46.6	$16.8	$19.4	$15.0

XML

Commitments and Contingencies Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended
	Jan. 31, 2022	Oct. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs			$ 32,367	$ 15,735
Entergy Wholesale Commodities [Member] | Indian Point
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party		$ 83,000
Damages awarded for previously recorded operation and maintenance	$ 47,000
Damages awarded for previously capitalized costs	32,000
Damages awarded for previously recorded taxes other than income taxes	$ 4,000

XML

Rate And Regulatory Matters (Narrative) (Details) - USD ($)	1 Months Ended									3 Months Ended		9 Months Ended	10 Months Ended	12 Months Ended
	Jul. 31, 2022	Apr. 30, 2022	Mar. 31, 2022	Feb. 28, 2022	Jan. 31, 2022	Aug. 31, 2021	Apr. 30, 2021	Mar. 31, 2021	Dec. 31, 1988	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2022	Jun. 30, 2021	Mar. 31, 2023	Mar. 31, 2022	Jan. 01, 2022	Dec. 31, 2021	Sep. 30, 2021	Apr. 30, 2020
Impairment of Long-Lived Assets Held-for-use										$ 744,000	$ 3,278,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress			$ 1,556,651,000							1,556,651,000					$ 1,556,651,000		$ 1,511,966,000
Proceeds from the issuance of long-term debt										2,553,369,000	3,676,242,000
Regulatory Asset [Abstract]
Long-term Transition Bond, Noncurrent			54,674,000							54,674,000					54,674,000		83,639,000
Deferred Fuel Cost			375,670,000							375,670,000					375,670,000		324,394,000
Long-term Transition Bond, Noncurrent			54,674,000							54,674,000					54,674,000		83,639,000
Entergy Louisiana [Member]
Public Utilities, Property, Plant and Equipment, Construction Work in Progress			721,536,000							721,536,000					721,536,000		847,924,000
Proceeds from the issuance of long-term debt										1,506,637,000	1,399,245,000
Storm Reserve Escrow Account				$ 290,000,000			$ 290,000,000
Regulatory Asset [Abstract]
Aggregate principal amount of system restoration bonds authorization requested				3,186,000,000
Deferred Fuel Cost			44,876,000							44,876,000					44,876,000		45,374,000
Reclassification from utility plant to other regulatory assets			1,339,000,000							1,339,000,000					1,339,000,000
Entergy Louisiana [Member] | Deferred COVID 19 Costs
Regulatory Asset [Abstract]
Regulatory Assets			47,800,000							47,800,000					47,800,000
Entergy Louisiana [Member] | Hurricane Ida
Deferred Storm and Property Reserve Deficiency, Noncurrent				1,000,000,000				$ 1,000,000,000			1,000,000,000							$ 1,000,000,000
Regulatory Asset [Abstract]
Aggregate principal amount of system restoration bonds authorization requested																		$ 1,000,000,000
Entergy Louisiana [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri
Total Restoration Costs For Repair and Replacement of Electrical System							2,060,000,000.00
Non-capital storm costs							380,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent				51,000,000			1,680,000,000
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs				2,100,000,000			$ 2,110,000,000
Entergy Louisiana [Member] | Subsequent Event [Member]
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs		$ 2,640,000,000
Regulatory Asset [Abstract]
Carrying costs associated with storm restoration costs												$ 3,000,000
Entergy Louisiana [Member] | Subsequent Event [Member] | Hurricane Ida
Total Restoration Costs For Repair and Replacement of Electrical System		2,540,000,000
Non-capital storm costs		586,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent		1,960,000,000
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs		2,600,000,000
Entergy Louisiana [Member] | Subsequent Event [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs		$ 32,000,000
Entergy Mississippi [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount			69,000,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress			$ 120,538,000							120,538,000					120,538,000		95,452,000
Proceeds from the issuance of long-term debt										0	200,573,000
Public Utilities, Requested Return on Equity, Percentage			6.70%
Interim increase in formula rate plan revenues			$ 34,500,000
Interim increase in formula rate plan revenues due to adjustments			24,300,000
Regulatory Asset [Abstract]
Deferred Fuel Cost			145,954,000							145,954,000					145,954,000		121,878,000
Entergy Mississippi [Member] | Formula Rate Plan Historical Year Rate Adjustment Member
Regulatory Asset [Abstract]
Regulatory Assets, Noncurrent																	19,000,000
Entergy Mississippi [Member] | Deferred COVID 19 Costs
Regulatory Asset [Abstract]
Regulatory Assets			14,100,000							14,100,000					14,100,000
Entergy Mississippi [Member] | Maximum [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount			$ 48,600,000
Public Utilities, Requested Rate Increase (Decrease), Percentage			4.00%
Entergy Mississippi [Member] | Subsequent Event [Member] | Maximum [Member]
Public Utilities, Requested Rate Increase (Decrease), Percentage	2.00%	2.00%
Entergy New Orleans [Member]
Public Utilities, Property, Plant and Equipment, Construction Work in Progress			$ 23,047,000							23,047,000					23,047,000		22,199,000
Regulatory Asset [Abstract]
Long-term Transition Bond, Noncurrent			29,721,000							29,721,000					29,721,000		29,661,000
Deferred Fuel Cost			2,352,000							2,352,000					2,352,000		0
Long-term Transition Bond, Noncurrent			29,721,000							29,721,000					29,721,000		29,661,000
Entergy New Orleans [Member] | Deferred COVID 19 Costs
Regulatory Asset [Abstract]
Regulatory Assets			14,500,000							14,500,000					14,500,000
Entergy New Orleans [Member] | Subsequent Event [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 40,200,000
Regulatory Asset [Abstract]
Earned return on common equity		6.88%
Authorized return on common equity		9.35%
Entergy New Orleans [Member] | Subsequent Event [Member] | Electricity [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 32,300,000
Regulatory Asset [Abstract]
Additional revenue increase due to previously approved amounts		4,700,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Natural Gas, US Regulated [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount		3,200,000
Entergy Texas [Member]
Public Utilities, Property, Plant and Equipment, Construction Work in Progress			207,167,000							207,167,000					207,167,000		183,965,000
Regulatory Asset [Abstract]
Long-term Transition Bond, Noncurrent			24,953,000							24,953,000					24,953,000		53,979,000
Deferred Fuel Cost			56,720,000							56,720,000					56,720,000		48,280,000
Long-term Transition Bond, Noncurrent			24,953,000							24,953,000					24,953,000		53,979,000
Entergy Texas [Member] | Deferred COVID 19 Costs
Regulatory Asset [Abstract]
Regulatory Assets			10,400,000							10,400,000					10,400,000
Entergy Texas [Member] | Hurricanes Laura and Delta and Winter Storm Uri
Regulatory Asset [Abstract]
Aggregate principal amount of system restoration bonds authorization requested																$ 242,900,000
Reclassification from utility plant to other regulatory assets			153,000,000							153,000,000					153,000,000
Entergy Texas [Member] | Subsequent Event [Member] | Aggregate Senior secured restoration bonds (securitization bonds)
Regulatory Asset [Abstract]
Proceeds from Issuance of Debt		290,850,000
Entergy Texas [Member] | Subsequent Event [Member] | Hurricanes Laura and Delta and Winter Storm Uri | Aggregate Senior secured restoration bonds (securitization bonds)
Regulatory Asset [Abstract]
Proceeds from Issuance of Debt		$ 290,850,000
Entergy Arkansas [Member]
Public Utilities, Property, Plant and Equipment, Construction Work in Progress			306,933,000							306,933,000					306,933,000		241,127,000
Proceeds from the issuance of long-term debt										212,060,000	604,760,000
Regulatory Asset [Abstract]
Energy Cost Recovery Rider Rate Per kWh															0.00959
Deferred Fuel Cost			125,767,000							125,767,000					125,767,000		108,862,000
Entergy Arkansas [Member] | Deferred COVID 19 Costs
Regulatory Asset [Abstract]
Regulatory Assets			34,400,000							34,400,000					34,400,000
Entergy Arkansas [Member] | 2021 February Winter Storms
Regulatory Asset [Abstract]
Deferred Fuel Cost			32,000,000							32,000,000					32,000,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Asset [Abstract]
Energy Cost Recovery Rider Rate Per kWh														$ 0.016390
Requested Energy Cost Recovery Rider Rate Per kWh														$ 0.01785
System Energy [Member]
Public Utilities, Property, Plant and Equipment, Construction Work in Progress			149,025,000							149,025,000					149,025,000		$ 97,968,000
Proceeds from the issuance of long-term debt										$ 225,956,000	$ 189,244,000
Regulatory Asset [Abstract]
Earned return on common equity										10.94%
Recommended adjustment to earned return on equity								9.32%
Estimated return on equity complaint refund										$ 61,000,000
Return on equity complaint, estimated annual rate reduction			50,000,000							50,000,000					50,000,000
Provision for rate refund			38,000,000							$ 38,000,000					38,000,000
System Energy [Member] | Maximum [Member]
Regulatory Asset [Abstract]
ALJ recommended equity capital structure, percentage								48.15%
Grand Gulf [Member] | System Energy [Member]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage										11.50%
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount						$ 40,200,000
Revenue increase resulting from incremental revenue													$ 13,900,000
Generation Cost Recovery Rider | Entergy Texas [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount				5,000,000	$ 88,300,000
Generation Cost Recovery Rider | Entergy Texas [Member] | Subsequent Event [Member]
Public Utilities, Requested Rate Increase (Decrease), Amount												92,800,000
Revenue increase resulting from incremental revenue												$ 4,500,000
Grand Gulf Sale-leaseback Renewal Complaint | System Energy [Member]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage									11.50%
Regulatory Asset [Abstract]
Refund of Lease Payments																			$ 17,200,000
Remaining net book value of the leased assets																			$ 70,000,000
Rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback			422,000,000							$ 422,000,000					422,000,000
Interest Portion of rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback			135,000,000							135,000,000					135,000,000
Refund related to depreciation expense adjustments			19,000,000							$ 19,000,000					$ 19,000,000
Unit Power Sales Agreement Complaint | System Energy [Member]
Regulatory Asset [Abstract]
FERC staff recommended refund			$ 84,100,000
New Orleans City Council Recommended Hypothetical Equity Ratio Prospectively																		48.15%
New Orleans City Council Witness Recommended Refund																		$ 98,800,000
System Energy Formula Rate Annual Protocols Formal Challenge | System Energy [Member]
Regulatory Asset [Abstract]
Estimated financial impact				$ 53,000,000

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Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions		1 Months Ended	3 Months Ended
	Apr. 11, 2022	Mar. 31, 2022	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Equity [Abstract]
Common stock dividend (in dollars per share)			$ 1.01	$ 0.95
Forward Sale Agreement, Aggregate Compensation to Sales Agents [Abstract]
Common Stock, Shares Authorized		499,000,000	499,000,000		499,000,000
Preferred Stock, Shares Authorized		1,000,000	1,000,000		1,000,000
Forward Sale Agreement, Aggregate Compensation to Sales Agents		$ 1.7
Stock Issued During Period, Shares, Treasury Stock Reissued			503,538
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount			900,000	1,000,000
Forward Contract Indexed to Issuer's Equity, Shares			1,538,010
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share			$ 108.14
Forward Contract Indexed to Equity, Settlement, Cash, Amount		168.0	$ 168.0
Equity Distribution Program
Equity [Abstract]
Equity Distribution Sales Agreement, Maximum Aggregate Gross Sales Price [Abstract]		1,000.0	$ 1,000.0
Forward Sale Agreement, Aggregate Compensation to Sales Agents [Abstract]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount			1,775,251
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 633.0	$ 633.0
System Energy [Member]
Forward Sale Agreement, Aggregate Compensation to Sales Agents [Abstract]
Common Stock, Shares Authorized		1,000,000	1,000,000		1,000,000
Entergy Texas [Member]
Forward Sale Agreement, Aggregate Compensation to Sales Agents [Abstract]
Common Stock, Shares Authorized		200,000,000	200,000,000		200,000,000
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 1.01

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Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net Income (Loss) Available to Common Stockholders, Basic	$ 276,400	$ 334,565
Net Income Attributable to Entergy Corporation, Shares	202,943,628	200,525,549
Net Income Attributable to Entergy Corporation, $/share	$ 1.36	$ 1.67
Net Income (Loss) Available to Common Stockholders, Diluted	$ 276,400	$ 334,600
Diluted earnings per share, Shares	203,888,483	201,059,665
Diluted earnings per share $/share	$ 1.36	$ 1.66
Employee Stock Option [Member]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	500,000	400,000
Average Dilutive Effect Of Stock Options Per Share	$ 0	$ (0.01)
Restricted Stock Units (RSUs) [Member]
Restricted stock, Shares	400,000	200,000
Restricted stock $/share	$ 0	$ 0
Forward Contracts [Member]
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements	100,000	0
Average Dilutive Effect Of Equity Forwards	$ 0	$ 0

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Equity (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	$ (336,578)	$ (500,507)	$ (332,528)	$ (449,207)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(15,889)	(43,819)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	11,839	(7,481)
Other comprehensive income (loss)	(4,050)	(51,300)
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(5,248)	11,963	7,154	56,650
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(15,875)	(45,301)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	3,473	614
Other comprehensive income (loss)	(12,402)	(44,687)
Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	(4,050)	(51,300)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(330,319)	(511,609)	(338,647)	(534,576)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	8,328	22,967
Other comprehensive income (loss)	8,328	22,967
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(1,011)	(861)	(1,035)	28,719
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(14)	1,482
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	38	(31,062)
Other comprehensive income (loss)	24	(29,580)
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	7,665		8,278
Other comprehensive income (loss)	(613)	(407)
Entergy Louisiana [Member] | Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	(613)	(407)
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	7,665	3,920	$ 8,278	$ 4,327
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(613)	(407)
Other comprehensive income (loss)	$ (613)	$ (407)

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Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,877,925	$ 2,844,838
Other Nonoperating Income (Expense)	7,603	(60,929)
Income taxes (benefits)	(66,497)	(65,942)
Consolidated net income	279,593	339,145
Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	149,788	248,250
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	(11,839)	7,481
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)	(48)	(48)
INCOME (LOSS) BEFORE INCOME TAXES	(48)	39,319
Income taxes (benefits)	10	(8,257)
Consolidated net income	(38)	31,062
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	39,367
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income taxes (benefits)	2,022	358
Consolidated net income	(3,473)	(614)
Realized Investment Gains (Losses)	(5,495)	(972)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	3,837	5,248
Amortization of loss	(13,925)	(34,529)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(782)	0
INCOME (LOSS) BEFORE INCOME TAXES	(10,870)	(29,281)
Income taxes (benefits)	2,542	6,314
Consolidated net income	(8,328)	(22,967)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,265,972	1,107,644
Other Nonoperating Income (Expense)	15,517	(34,638)
Income taxes (benefits)	(30,789)	(37,772)
Consolidated net income	150,860	166,626
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	1,158	1,230
Amortization of loss	(319)	(679)
INCOME (LOSS) BEFORE INCOME TAXES	839	551
Income taxes (benefits)	(226)	(144)
Consolidated net income	$ 613	$ 407

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Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) $ in Thousands	1 Months Ended			3 Months Ended
	Apr. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Mar. 31, 2022 USD ($)	Dec. 31, 2026 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Feb. 28, 2022 USD ($)	Jan. 01, 2022 USD ($)
Debt Instrument [Line Items]
Amount of Facility		$ 3,500,000		$ 3,500,000
Amount Drawn/ Outstanding		$ 150,000		$ 150,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate		0.48%		0.48%
Commercial Paper program limit		$ 2,000,000		$ 2,000,000
Commercial Paper Amount Outstanding		1,343,000		1,343,000
Credit Facility [Member]
Debt Instrument [Line Items]
Amount of Facility		3,500,000		3,500,000
Amount of total borrowing capacity against which fronting commitments exist		20,000		$ 20,000
Line of credit facility, commitment fee percentage				0.225%
Line of Credit Facility, Interest Rate During Period				1.81%
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		250,000		$ 250,000
Amount of total borrowing capacity against which fronting commitments exist		5,000		5,000
Letters of Credit Outstanding, Amount		300		$ 300
Entergy Arkansas [Member] | 4.20% Series mortgage bonds due April 2049
Debt Instrument [Line Items]
Proceeds from Issuance of Debt		$ 200,000
Debt instrument, interest rate, stated percentage		4.20%		4.20%
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 450,000		$ 450,000
Amount of total borrowing capacity against which fronting commitments exist		$ 15,000		$ 15,000
Aggregate principal amount of system restoration bonds authorization requested										$ 3,186,000
Entergy Louisiana [Member] | Unsecured Term Loan due June 2023
Debt Instrument [Line Items]
Debt, weighted average interest rate		0.976%		0.976%
Proceeds from Issuance of Debt			$ 1,200,000
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 200,000		$ 200,000
Letters of Credit Outstanding, Amount		400	200	400
Non-MISO letter of credit outstanding		1,000		1,000
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		200,000		200,000
Amount of total borrowing capacity against which fronting commitments exist		30,000		30,000
Letters of Credit Outstanding, Amount			$ 100
Entergy Texas [Member] | Hurricanes Laura and Delta and Winter Storm Uri
Debt Instrument [Line Items]
Aggregate principal amount of system restoration bonds authorization requested											$ 242,900
System Restoration Regulatory Asset											$ 13,300
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		200,000		200,000
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		150,000		150,000
Amount of total borrowing capacity against which fronting commitments exist		10,000		10,000
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		100,000		$ 100,000
Line of Credit Facility, Interest Rate During Period				1.17%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.10%
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				1.10%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.10%
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		82,100		$ 82,100
Line of Credit Facility, Interest Rate During Period				1.15%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.10%
Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		30,800		$ 30,800
Line of Credit Facility, Interest Rate During Period				1.14%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.10%
Entergy Nuclear Vermont Yankee
Debt Instrument [Line Items]
Amount of Facility		139,000		$ 139,000
Amount Drawn/ Outstanding		$ 139,000		$ 139,000
Debt, weighted average interest rate		1.72%		1.72%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.20%
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage				0.375%
Consolidated debt ratio		0.65		0.65
Maximum [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65		0.65
Consolidated debt ratio of total capitalization				70.00%
Maximum [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65		0.65
Consolidated debt ratio of total capitalization				70.00%
Maximum [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65		0.65
Maximum [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65		0.65
Maximum [Member] | System Energy [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65		0.65
Consolidated debt ratio of total capitalization				70.00%
Maximum [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65		0.65
Minimum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage				0.075%
Credit Facility Of Three Hundred Fifty Million [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Amount of Facility		$ 350,000		$ 350,000
Letters of Credit Outstanding, Amount		0		0
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				1.71%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000		$ 150,000
Letters of Credit Outstanding, Amount		0		0
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				1.58%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000		$ 150,000
Letters of Credit Outstanding, Amount		1,300		1,300
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				1.71%
Credit Facility Of Thirty Seven Point Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility		37,500		$ 37,500
Letters of Credit Outstanding, Amount		0		0
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				1.96%
Credit Facility Of Thirty Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility		35,000		$ 35,000
Letters of Credit Outstanding, Amount		0		0
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				1.96%
Credit Facility Of Ten Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility		10,000		$ 10,000
Letters of Credit Outstanding, Amount		0		0
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				1.96%
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility		25,000		$ 25,000
Letters of Credit Outstanding, Amount		0		0
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				3.00%
Credit Facility Of Twenty Five Million [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Amount of Facility		25,000		$ 25,000
Letters of Credit Outstanding, Amount		0		0
Amount Drawn/ Outstanding		0		$ 0
Line of Credit Facility, Interest Rate During Period				2.08%
Subsequent Event [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	$ 95,000
Subsequent Event [Member] | Entergy Texas [Member] | 3.697% Senior Secured System Restoration Bonds Series 2022-A Due December 2036
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 190,850
Debt instrument, interest rate, stated percentage	3.697%
Subsequent Event [Member] | Entergy Texas [Member] | 3.051% Senior Secured System Restoration Bonds Series 2022-A Due December 2028
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 100,000
Debt instrument, interest rate, stated percentage	3.051%
Subsequent Event [Member] | Entergy Texas [Member] | Aggregate Senior secured restoration bonds (securitization bonds)
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 290,850
Subsequent Event [Member] | Entergy Texas [Member] | Aggregate Senior secured restoration bonds (securitization bonds) | Hurricanes Laura and Delta and Winter Storm Uri
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	290,850
Subsequent Event [Member] | Entergy Texas [Member] | Tranche A-1 3.051% due December 2028
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months									$ 12,300
Long-term Debt, Maturities, Repayments of Principal in Year Two								$ 17,800
Long-term Debt, Maturities, Repayments of Principal in Year Three							$ 18,300
Long-term Debt, Maturities, Repayments of Principal in Year Four						$ 18,800
Long-term Debt, Maturities, Repayments of Principal in Year Five					$ 19,400
Subsequent Event [Member] | Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	$ 150,000
Credit Facility of Sixty Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		2,300		$ 2,300
Uncommitted Credit Facility		$ 65,000		$ 65,000

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Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) - USD ($) $ in Millions	Apr. 30, 2022	Mar. 31, 2022
Summary of the borrowings outstanding and capacity available under the facility
Capacity		$ 3,500
Amount Drawn/ Outstanding		150
Letters of Credit		3
Capacity Available		3,347
Line of Credit Facility [Line Items]
Amount of Facility		3,500
Credit Facility [Member]
Summary of the borrowings outstanding and capacity available under the facility
Capacity		3,500
Line of Credit Facility [Line Items]
Amount of Facility		3,500
Entergy Mississippi [Member] | Subsequent Event [Member]
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 95
Line of Credit Facility [Line Items]
Amount of Facility	95
Credit Facility Of Thirty Five Million [Member] | Entergy Mississippi [Member]
Summary of the borrowings outstanding and capacity available under the facility
Capacity		35
Amount Drawn/ Outstanding		0
Line of Credit Facility [Line Items]
Amount of Facility		$ 35
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Mississippi [Member] | Subsequent Event [Member]
Summary of the borrowings outstanding and capacity available under the facility
Capacity	150
Line of Credit Facility [Line Items]
Amount of Facility	$ 150

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Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Amount of Facility	$ 3,500.0
Amount Drawn/ Outstanding	150.0
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	5.0
Letters of Credit Outstanding, Amount	0.3
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member]
Amount of Facility	$ 25.0
Interest Rate	3.00%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	0.0
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Amount of Facility	$ 150.0
Interest Rate	1.58%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	0.0
Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	15.0
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Amount of Facility	$ 350.0
Interest Rate	1.71%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	0.0
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	0.4	$ 0.2
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Amount of Facility	$ 37.5
Interest Rate	1.96%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	0.0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Amount of Facility	$ 35.0
Interest Rate	1.96%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	0.0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Amount of Facility	$ 10.0
Interest Rate	1.96%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	0.0
Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	10.0
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Amount of Facility	$ 25.0
Interest Rate	2.08%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	0.0
Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	30.0
Letters of Credit Outstanding, Amount		$ 0.1
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Amount of Facility	$ 150.0
Interest Rate	1.71%
Amount Drawn/ Outstanding	$ 0.0
Letters of Credit Outstanding, Amount	$ 1.3

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Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Mar. 31, 2022 USD ($)
Entergy Arkansas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	$ 250
Borrowings	0
Entergy Louisiana [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	450
Borrowings	0
Entergy Mississippi [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	22
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	150
Borrowings	0
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	171
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

XML

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 150.0
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 80.0
Line of Credit Facility, Interest Rate During Period	1.10%
Amount Drawn/ Outstanding	$ 0.0
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 120.0
Line of Credit Facility, Interest Rate During Period	1.17%
Amount Drawn/ Outstanding	$ 100.0
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana River Bend VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 105.0
Line of Credit Facility, Interest Rate During Period	1.14%
Amount Drawn/ Outstanding	$ 30.8
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 105.0
Line of Credit Facility, Interest Rate During Period	1.15%
Amount Drawn/ Outstanding	$ 82.1
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%

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Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Mar. 31, 2022 USD ($)
Three Point One Seven Percent Series M Notes Due December Two Thousand Twenty Three [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.17%
Amount	$ 40
Three Point Two Two Percent Series I Notes Due December Two Thousand Twenty Three [Domain] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.22%
Amount	$ 20
Two Point Fifty One Percent Series V Notes Due June 2027 | Entergy Louisiana River Bend VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	2.51%
Amount	$ 70
Two Point Zero Five Percent Series K Notes Due September 2027 | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	2.05%
Amount	$ 90
One Point Eight Four Percent Series N Notes Due July Two Thousand Twenty Six | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	1.84%
Amount	$ 90

XML

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Book Value And The Fair Value Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Long-term Debt, Fair Value	$ 26,731,277	$ 27,061,171
Long-term Debt, Book Value	27,215,784	25,880,901
Entergy Arkansas [Member]
Long-term Debt, Fair Value	4,101,516	4,176,577
Long-term Debt, Book Value	4,163,602	3,958,862
Entergy Louisiana [Member]
Long-term Debt, Fair Value	11,959,123	11,492,650
Long-term Debt, Book Value	12,022,131	10,914,346
Entergy Mississippi [Member]
Long-term Debt, Fair Value	2,152,275	2,346,230
Long-term Debt, Book Value	2,180,197	2,179,989
Entergy New Orleans [Member]
Long-term Debt, Fair Value	775,566	765,538
Long-term Debt, Book Value	788,501	788,165
Entergy Texas [Member]
Long-term Debt, Fair Value	2,254,487	2,483,995
Long-term Debt, Book Value	2,325,371	2,354,148
System Energy [Member]
Long-term Debt, Fair Value	769,552	743,040
Long-term Debt, Book Value	$ 805,353	$ 741,296

XML

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	$ 0.3
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	0.4	$ 0.2
Entergy Texas [Member]
Letters of Credit Outstanding, Amount		$ 0.1
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25.0
Letter of Credit Fee, Percentage	0.78%
Letters of Credit Outstanding, Amount	$ 7.5
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 80.0
Letter of Credit Fee, Percentage	0.875%
Letters of Credit Outstanding, Amount	$ 79.6
Credit Facility of Fifteen Million [Member] | Entergy New Orleans [Member]
Uncommitted Credit Facility	$ 15.0
Letter of Credit Fee, Percentage	1.00%
Letters of Credit Outstanding, Amount	$ 1.0
Credit Facility Of One Hundred Twenty Five Million [Member] | Entergy Louisiana [Member]
Uncommitted Credit Facility	$ 125.0
Letter of Credit Fee, Percentage	0.78%
Letters of Credit Outstanding, Amount	$ 11.0
Credit Facility of Sixty Five Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 65.0
Letter of Credit Fee, Percentage	0.78%
Letters of Credit Outstanding, Amount	$ 2.3

XML

Stock Based Compensation (Narrative) (Details) - 2019 Omnibus Incentive Plan - USD ($) $ / shares in Units, $ in Millions		1 Months Ended	3 Months Ended
	Jan. 27, 2022	Jan. 31, 2022	Mar. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)			444,028
Weighted-average grant-date fair value of options granted (in dollars per share)			$ 16.25
Stock options outstanding			3,128,304
Weighted-average exercise price of stock options outstanding (in dollars per share)			$ 94.35
Intrinsic value in the money stock options			$ 77.6
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted		328,849
Restricted stock awards granted value (in dollars per share)		$ 109.59
Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-term incentive plan awards		170,966
Percent of performance measure based on relative total shareholder return	80.00%		80.00%
Percent of performance measure based on cumulative adjusted EPS metric	20.00%		20.00%
Long Term Incentive Plan [Member] | Performance measure based on relative total shareholder return [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted value (in dollars per share)	$ 138.99
Long Term Incentive Plan [Member] | Performance measure based on cumulative adjusted earnings per share metric [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted value (in dollars per share)	$ 109.59

XML

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.1	$ 1.0
Tax benefit recognized in Entergy's net income	0.3	0.3
Compensation cost capitalized as part of fixed assets and inventory	$ 0.4	$ 0.4

XML

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Other Equity Awards [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 11.4	$ 10.8
Tax benefit recognized in Entergy's net income	2.9	2.7
Compensation cost capitalized as part of fixed assets and inventory	$ 4.4	$ 4.0

XML

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2022
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 200,000
Defined Benefit Plan, Plan Assets, Contributions by Employer	67,900
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	40,840
Defined Benefit Plan, Plan Assets, Contributions by Employer	15,096
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	22,917
Defined Benefit Plan, Plan Assets, Contributions by Employer	10,241
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	12,852
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,972
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	922
Defined Benefit Plan, Plan Assets, Contributions by Employer	922
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	1,924
Defined Benefit Plan, Plan Assets, Contributions by Employer	1,340
Difference between rate case pension amounts and actuarially determined pension amounts	14,500
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	12,760
Defined Benefit Plan, Plan Assets, Contributions by Employer	3,996
Subsequent Event [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			$ 25,744
Subsequent Event [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			12,676
Subsequent Event [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			9,880
Subsequent Event [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			0
Subsequent Event [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			584
Subsequent Event [Member] | System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			$ 8,764
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	10,200	$ 4,600
Defined Benefit Plan, Benefit Obligation, Payment for Settlement	5,300
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	72	90
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	27	44
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	80	96
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	29	8
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	215	115
Defined Benefit Plan, Benefit Obligation, Payment for Settlement	119
Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	45,751	90,019
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	10,354	15,392
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	11,100	16,271
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	3,415	4,907
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	744	1,473
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	1,425	2,224
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	$ 3,026	$ 5,004

XML

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 37,660	$ 45,241
Interest cost on projected benefit obligation	51,119	46,099
Expected return on assets	(103,607)	(105,713)
Amortization of loss	60,579	104,392
Net other postretirement benefit cost	45,751	90,019
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,858	7,418
Interest cost on projected benefit obligation	9,317	8,341
Expected return on assets	(19,247)	(19,670)
Amortization of loss	13,426	19,303
Net other postretirement benefit cost	10,354	15,392
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	9,137	10,043
Interest cost on projected benefit obligation	10,499	9,562
Expected return on assets	(21,133)	(22,538)
Amortization of loss	12,597	19,204
Net other postretirement benefit cost	11,100	16,271
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	2,130	2,364
Interest cost on projected benefit obligation	2,678	2,462
Expected return on assets	(5,203)	(5,587)
Amortization of loss	3,810	5,668
Net other postretirement benefit cost	3,415	4,907
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	752	796
Interest cost on projected benefit obligation	1,139	1,029
Expected return on assets	(2,515)	(2,622)
Amortization of loss	1,368	2,270
Net other postretirement benefit cost	744	1,473
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,632	1,801
Interest cost on projected benefit obligation	2,175	1,949
Expected return on assets	(4,937)	(5,237)
Amortization of loss	2,555	3,711
Net other postretirement benefit cost	1,425	2,224
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	2,045	2,314
Interest cost on projected benefit obligation	2,338	2,142
Expected return on assets	(4,623)	(4,778)
Amortization of loss	3,266	5,326
Net other postretirement benefit cost	3,026	5,004
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,184	6,645
Interest cost on projected benefit obligation	6,827	5,320
Expected return on assets	(10,855)	(10,805)
Amortization of prior service cost (credit)	(6,388)	(8,267)
Amortization of loss	1,083	713
Net other postretirement benefit cost	(3,149)	(6,394)
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,114	1,034
Interest cost on projected benefit obligation	1,263	932
Expected return on assets	(4,483)	(4,505)
Amortization of prior service cost (credit)	471	(280)
Amortization of loss	218	49
Net other postretirement benefit cost	(1,417)	(2,770)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,408	1,544
Interest cost on projected benefit obligation	1,443	1,130
Expected return on assets	0	0
Amortization of prior service cost (credit)	(1,158)	(1,230)
Amortization of loss	(186)	(91)
Net other postretirement benefit cost	1,507	1,353
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	339	362
Interest cost on projected benefit obligation	350	278
Expected return on assets	(1,394)	(1,384)
Amortization of prior service cost (credit)	(443)	(444)
Amortization of loss	56	19
Net other postretirement benefit cost	(1,092)	(1,169)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	99	109
Interest cost on projected benefit obligation	174	130
Expected return on assets	(1,499)	(1,438)
Amortization of prior service cost (credit)	(229)	(229)
Amortization of loss	(225)	(178)
Net other postretirement benefit cost	(1,680)	(1,606)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	331	346
Interest cost on projected benefit obligation	399	317
Expected return on assets	(2,568)	(2,548)
Amortization of prior service cost (credit)	(1,093)	(936)
Amortization of loss	162	100
Net other postretirement benefit cost	(2,769)	(2,721)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	310	335
Interest cost on projected benefit obligation	279	220
Expected return on assets	(791)	(789)
Amortization of prior service cost (credit)	(80)	(109)
Amortization of loss	30	15
Net other postretirement benefit cost	(252)	(328)
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	10,200	4,600
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	72	90
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	27	44
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	80	96
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	29	8
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 215	$ 115

XML

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Mar. 31, 2022	Dec. 31, 2022
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 200,000
Defined Benefit Plan, Plan Assets, Contributions by Employer	67,900
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	22,917
Defined Benefit Plan, Plan Assets, Contributions by Employer	10,241
Entergy Louisiana [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer		$ 12,676
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	12,852
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,972
Entergy Mississippi [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer		9,880
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	922
Defined Benefit Plan, Plan Assets, Contributions by Employer	922
Entergy New Orleans [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer		0
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	1,924
Defined Benefit Plan, Plan Assets, Contributions by Employer	1,340
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer		584
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	12,760
Defined Benefit Plan, Plan Assets, Contributions by Employer	3,996
System Energy [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer		8,764
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	40,840
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 15,096
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer		$ 25,744

XML

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 3,837	$ 5,248
Amortization of loss	(13,925)	(34,529)
Total	(10,870)	(29,281)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(782)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,158	1,230
Amortization of loss	(319)	(679)
Total	839	551
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(12,910)	(33,439)
Total	(12,910)	(33,439)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(504)	(769)
Total	(504)	(769)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	4,014	5,288
Amortization of loss	(596)	(495)
Total	3,418	4,793
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,158	1,230
Amortization of loss	186	91
Total	1,344	1,321
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(177)	(40)
Amortization of loss	(419)	(595)
Total	(1,378)	(635)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(782)
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(1)	(1)
Total	$ (1)	$ (1)

XML

Business Segment Information Business Segment Information (Narrative) (Details) - Entergy Wholesale Commodities [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 1	$ 3
Restructuring Charges	4	13
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 4	$ 13

XML

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,877,925	$ 2,844,838
Segment Financial Information
Income taxes (benefits)	66,497	65,942
Consolidated net income	279,593	339,145
Assets	59,833,526		$ 59,454,242
Utility [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,728,156	2,596,616
Segment Financial Information
Income taxes (benefits)	75,359	59,734
Consolidated net income	343,156	360,600
Assets	61,684,609		59,733,625
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	149,777	248,219
Segment Financial Information
Income taxes (benefits)	2,854	15,560
Consolidated net income	7,859	38,124
Assets	1,137,843		1,242,675
All Other [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	23
Segment Financial Information
Income taxes (benefits)	(11,716)	(9,352)
Consolidated net income	(39,476)	(27,680)
Assets	601,479		561,168
Eliminations
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(8)	(20)
Segment Financial Information
Income taxes (benefits)	0	0
Consolidated net income	(31,946)	$ (31,899)
Assets	$ (3,590,405)		$ (2,083,226)

XML

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - Entergy Wholesale Commodities [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Restructuring Charges	$ 4	$ 13
Restructuring Reserve	41	171		$ 37	$ 159
Payments for Restructuring	0	1
Asset Write-Offs, Impairments, And Related Charges	1	3
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	4	13
Restructuring Reserve	41	157		37	145
Payments for Restructuring	0	1
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Reserve			$ 5
Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	0	0
Restructuring Reserve	0	14		$ 0	$ 14
Payments for Restructuring	$ 0	$ 0

XML

Risk Management and Fair Values (Narrative) (Details) TWh in Millions, $ in Millions	2 Months Ended	3 Months Ended
	May 31, 2022 TWh	Mar. 31, 2022 USD ($) GWh MMBTU	Mar. 31, 2021 USD ($)	Dec. 31, 2021 USD ($)
Maturity of cash flow hedges, Tax			$ 8.0
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		37,339,100
Total volume of fixed transmission rights outstanding | GWh		23,303
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings			0.7
Debt Securities, Available-for-sale, Allowance for Credit Loss		$ 3.2		$ 0.4
Letters Of Credit		3.0
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount		$ 0.3
Total volume of fixed transmission rights outstanding | GWh		4,969
Entergy Louisiana [Member]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		14,620,000
Total volume of fixed transmission rights outstanding | GWh		10,681
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount		$ 0.4		0.2
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		22,719,100
Total volume of fixed transmission rights outstanding | GWh		2,529
Entergy New Orleans [Member]
Total volume of fixed transmission rights outstanding | GWh		1,070
Entergy Texas [Member]
Letters of Credit Outstanding, Amount				0.1
Total volume of fixed transmission rights outstanding | GWh		3,959
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge		2 years
Gas Hedge Contracts [Member] | Entergy Mississippi [Member]
Maximum Length of Time Hedged in Cash Flow Hedge		7 months
Electricity Swaps And Options [Member] | Cash Flow Hedging [Member] | Competitive Businesses Operating Revenues [Member]
Maturity of cash flow hedges, before taxes			$ 39.0
Entergy Wholesale Commodities [Member]
Cash collateral posted		$ 8.0		$ 8.0
Utility [Member]
Letters Of Credit		$ 1.0
Subsequent Event [Member]
Planned generation sold forward from non utility nuclear power plants for the remainder of the period	99.00%
Total planned generation for remainder of the period | TWh	1.1

XML

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	$ 8.0	$ 8.0
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	8.0	5.0
Derivative Asset, Fair Value, Gross Asset	8.0	5.0
Derivative, Collateral, Obligation to Return Cash		0.0
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	54.0	6.0
Derivative Asset, Fair Value, Gross Asset	54.0	6.0
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.0	4.0
Derivative Asset, Fair Value, Gross Asset	2.0	4.0
Derivative, Collateral, Obligation to Return Cash	(1.0)	0.0
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		7.0
Derivative, Collateral, Right to Reclaim Cash		0.0
Derivative Liability		7.0
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	8.3	5.3
Derivative Asset, Fair Value, Gross Asset	8.3	5.3
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	19.3	5.7
Derivative Asset, Fair Value, Gross Asset	19.3	5.7
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.3	0.6
Derivative Asset, Fair Value, Gross Asset	0.3	0.6
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.4	0.2
Entergy Mississippi [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	35.0
Derivative Asset, Fair Value, Gross Asset	35.0
Derivative, Collateral, Obligation to Return Cash	0.0
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.2	0.3
Derivative Asset, Fair Value, Gross Asset	0.2	0.3
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		6.7
Derivative, Collateral, Right to Reclaim Cash		0.0
Derivative Liability		6.7
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.1	0.1
Derivative Asset, Fair Value, Gross Asset	0.1	0.1
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		0.5
Derivative, Collateral, Right to Reclaim Cash		0.0
Derivative Liability		0.5
Entergy Arkansas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.3
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.4	2.3
Derivative Asset, Fair Value, Gross Asset	0.6	2.3
Derivative, Collateral, Obligation to Return Cash	(0.2)	0.0
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount		0.1
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.5	0.8
Derivative Asset, Fair Value, Gross Asset	0.5	0.8
Derivative, Collateral, Obligation to Return Cash	$ 0.0	$ 0.0

XML

Risk Management and Fair Values (Derivative Instruments Designated as Cash Flow Hedges On Consolidated Statements Of Income) (Details) - Competitive Businesses Operating Revenues [Member] - Electricity Swaps And Options [Member] - Cash Flow Hedging [Member] $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($)
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 39
Unrealized Gain (Loss) on Derivatives	$ 2

XML

Risk Management and Fair Values (Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Competitive Businesses Operating Revenues [Member] | Electricity Swaps And Options [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net		$ (2.0)
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 55.0	7.0
Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	23.0	128.0
Entergy Arkansas [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	0.3
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.4		$ 2.3
Entergy Arkansas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	7.5	26.1
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.3		0.6
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Deferred Debits And Other Assets [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	8.3		5.3
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	19.3		5.7
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	11.1	1.8
Entergy Louisiana [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	9.4	12.3
Entergy Mississippi [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	0.4		0.2
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.2		0.3
Entergy Mississippi [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Current Liabilities [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Liability, Fair Value, Gross Liability			6.7
Derivative, Collateral, Right to Reclaim Cash			0.0
Derivative Liability			6.7
Entergy Mississippi [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	35.0
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	42.8	5.2
Entergy Mississippi [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	1.0	7.2
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.1		0.1
Entergy New Orleans [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Current Liabilities [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Liability, Fair Value, Gross Liability			0.5
Derivative, Collateral, Right to Reclaim Cash			0.0
Derivative Liability			0.5
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	1.1	(0.1)
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0.8	1.3
Entergy Texas [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount			0.1
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.5		$ 0.8
Entergy Texas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 3.8	$ 77.9

XML

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	$ 625,445	$ 397,615
Assets at fair value on a recurring basis
Securitization recovery trust account	15,000	29,000
Replacement Reserve Escrow	49,000	49,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	5,965,000	6,005,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		7,000
Debt Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	2,070,000	2,177,000
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	3,040,000	3,205,000
Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	62,000	11,000
Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000	4,000
Equity Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	103,000	132,000
Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	625,000	398,000
Assets at fair value on a recurring basis
Securitization recovery trust account	15,000	29,000
Replacement Reserve Escrow	49,000	49,000
Equity Securities, FV-NI	103,000	132,000
Debt Securities	736,000	770,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,582,000	1,384,000
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		7,000
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	54,000	6,000
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Securitization recovery trust account	0	0
Replacement Reserve Escrow	0	0
Equity Securities, FV-NI	0	0
Debt Securities	1,334,000	1,407,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,342,000	1,412,000
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	8,000	5,000
Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Securitization recovery trust account	0	0
Replacement Reserve Escrow	0	0
Equity Securities, FV-NI	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,000	4,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000	4,000
Entergy New Orleans [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	31,139	42,836
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	5,098	1,999
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	36,300	44,900
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		500
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	100	100
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	31,100	42,800
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	5,100	2,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	36,200	44,800
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		500
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	100	100
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	100	100
Entergy Mississippi [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	2	47,598
Assets at fair value on a recurring basis
Replacement Reserve Escrow	48,900	48,900
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	84,100	96,800
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		6,700
Entergy Mississippi [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	35,000
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	200	300
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		47,600
Assets at fair value on a recurring basis
Replacement Reserve Escrow	48,900	48,900
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	83,900	96,500
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		6,700
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	35,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	200	300
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	200	300
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	140,714	18,378
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	2,174,000	2,144,500
Entergy Louisiana [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	747,500	794,200
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	1,235,100	1,300,100
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	27,600	11,000
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	300	600
Entergy Louisiana [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	22,800	20,200
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	140,700	18,400
Assets at fair value on a recurring basis
Equity Securities, FV-NI	22,800	20,200
Debt Securities	230,000	262,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	412,800	306,900
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	19,300	5,700
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0	0
Debt Securities	517,500	531,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	525,800	536,900
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	8,300	5,300
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	300	600
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	300	600
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	107,179	4,760
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,468,200	1,445,500
Entergy Arkansas [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	509,300	526,300
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	848,600	895,400
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	400	2,300
Entergy Arkansas [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	2,700	16,700
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	107,200	4,800
Assets at fair value on a recurring basis
Equity Securities, FV-NI	2,700	16,700
Debt Securities	132,400	119,500
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	242,300	141,000
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0	0
Debt Securities	376,900	406,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	376,900	406,800
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	400	2,300
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	400	2,300
Entergy Texas [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	9,998	26,629
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	10,500	27,400
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	500	800
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	10,000	26,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	10,000	26,600
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	500	800
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	500	800
System Energy [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	98,183	89,114
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,406,400	1,474,400
System Energy [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	499,600	524,500
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	803,700	847,900
System Energy [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Decommissioning Fund Investments, Fair Value	4,900	12,900
System Energy [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	98,200	89,100
Assets at fair value on a recurring basis
Equity Securities, FV-NI	4,900	12,900
Debt Securities	251,500	273,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	354,600	375,000
System Energy [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0	0
Debt Securities	248,100	251,500
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	248,100	251,500
System Energy [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	$ 0	$ 0

XML

Risk Management and Fair Values (Reconciliation Of Changes In The Net Assets (Liabilities) For The Fair Value Of Derivatives Classified As Level 3 In The Fair Value Hierarchy) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Electricity Swaps And Options [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value		$ 0.0		$ 38.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)		2.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset		0.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements		(38.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings		(2.0)
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 1.0	4.0	$ 4.0	9.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	0.0	4.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0.0	0.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	20.0	119.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(23.0)	(128.0)
Fixed Transmission Rights (FTRs) [Member] | Entergy Arkansas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.4	1.4	2.3	2.7
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		24.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	5.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(7.5)	(26.1)
Fixed Transmission Rights (FTRs) [Member] | Entergy Louisiana [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.3	1.2	0.6	4.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		9.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	9.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(9.4)	(12.3)
Fixed Transmission Rights (FTRs) [Member] | Entergy Mississippi [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.2	0.3	0.3	0.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		6.9
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0.9
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	1.0	7.2
Fixed Transmission Rights (FTRs) [Member] | Entergy New Orleans [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.1	0.1	0.1	0.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		1.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	0.8	1.2
Fixed Transmission Rights (FTRs) [Member] | Entergy Texas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.5	0.5	$ 0.8	$ 1.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		76.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	3.5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	$ (3.8)	$ (77.9)

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Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) - Gas Hedge Contracts [Member]	3 Months Ended
	Mar. 31, 2022
Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	2 years
Entergy Mississippi [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	7 months

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Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	$ 7,221	$ 25,581
Amortized cost of debt securities	$ 2,153,000		$ 2,125,000
Average coupon rate of debt securities	2.77%
Average duration of debt securities, years	6 years 7 months 17 days
Average maturity of debt securities, years	10 years 4 months 24 days
Proceeds from the dispositions of debt securities	$ 303,000	524,000
Debt Securities, Available-for-sale, Allowance for Credit Loss	3,200		400
Equity Securities, FV-NI, Unrealized Loss	(175,000)
Debt Securities, Available-for-sale, Realized Gain	1,000	11,000
Debt Securities, Available-for-sale, Realized Loss	12,000	11,000
Other-than-temporary Impairment Loss, Debt Securities, Available-for-sale	1,500
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	(5,000)		2,000
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 536,200		519,600
Average coupon rate of debt securities	2.28%
Average duration of debt securities, years	6 years 5 months 26 days
Average maturity of debt securities, years	7 years 8 months 26 days
Proceeds from the dispositions of debt securities	$ 7,200	13,800
Equity Securities, FV-NI, Unrealized Loss	(50,500)
Debt Securities, Available-for-sale, Realized Gain	30	800
Debt Securities, Available-for-sale, Realized Loss	200	100
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 767,900		766,300
Average coupon rate of debt securities	3.37%
Average duration of debt securities, years	6 years 4 months 9 days
Average maturity of debt securities, years	12 years 1 month 28 days
Proceeds from the dispositions of debt securities	$ 120,500	108,400
Percentage Interest in River Bend	30.00%
Equity Securities, FV-NI, Unrealized Loss	$ (70,000)
Debt Securities, Available-for-sale, Realized Gain	900	3,300
Debt Securities, Available-for-sale, Realized Loss	5,500	3,200
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 525,300		515,600
Average coupon rate of debt securities	2.38%
Average duration of debt securities, years	6 years 11 months 19 days
Average maturity of debt securities, years	9 years 10 months 13 days
Proceeds from the dispositions of debt securities	$ 36,200	74,100
Equity Securities, FV-NI, Unrealized Loss	(47,700)
Debt Securities, Available-for-sale, Realized Gain	100	1,200
Debt Securities, Available-for-sale, Realized Loss	700	$ 1,600
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 539,000		$ 576,000

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Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Total	$ 2,070.0	$ 2,177.0
Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	99.0	12.0
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	15.0	65.0
Total	2,070.0	2,177.0
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Total	509.3	526.3
Entergy Arkansas [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	28.3	4.7
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	1.4	11.4
Total	509.3	526.3
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Total	747.5	794.2
Entergy Louisiana [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	30.2	3.3
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	9.7	31.3
Total	747.5	794.2
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Total	499.6	524.5
System Energy [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	27.6	2.9
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	1.9	11.8
Total	$ 499.6	$ 524.5

XML

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	$ 1,419.0	$ 770.0
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	119.0	99.0
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	1,538.0	869.0
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	83.0	8.0
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	16.0	4.0
Debt Securities, Available-for-sale, Unrealized Loss Position	99.0	12.0
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	332.9	183.8
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	55.8	39.5
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	388.7	223.3
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	21.3	2.9
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	7.0	1.8
Debt Securities, Available-for-sale, Unrealized Loss Position	28.3	4.7
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	427.4	206.9
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	41.2	42.9
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	468.6	249.8
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	25.1	1.4
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	5.1	1.9
Debt Securities, Available-for-sale, Unrealized Loss Position	30.2	3.3
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	418.4	276.6
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	13.3	11.3
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	431.7	287.9
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	25.5	2.3
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	2.1	0.6
Debt Securities, Available-for-sale, Unrealized Loss Position	$ 27.6	$ 2.9

XML

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Fair value of debt securities by contractual maturities
1 year - 5 years	$ 692.0	$ 473.0
5 years - 10 years	600.0	655.0
10 years - 15 years	150.0	389.0
15 years - 20 years	158.0	130.0
20 years+	394.0	530.0
Total	2,070.0	2,177.0
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	76.0	0.0
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	153.6	91.7
5 years - 10 years	220.8	217.4
10 years - 15 years	47.9	146.0
15 years - 20 years	27.3	35.7
20 years+	25.9	35.5
Total	509.3	526.3
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	33.8	0.0
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	193.9	157.8
5 years - 10 years	170.0	173.0
10 years - 15 years	68.5	123.0
15 years - 20 years	82.9	80.2
20 years+	203.0	260.2
Total	747.5	794.2
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	29.2	0.0
System Energy [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	217.3	156.8
5 years - 10 years	136.1	161.8
10 years - 15 years	9.5	58.6
15 years - 20 years	31.1	1.9
20 years+	98.7	145.4
Total	499.6	524.5
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	$ 6.9	$ 0.0

XML

Income Taxes Income Taxes (Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 17	$ 41
Entergy Arkansas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	0	8
Entergy Louisiana [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	9	8
Entergy New Orleans [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	1	0
Entergy Texas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	7	7
System Energy [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 0	$ 18

XML

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Construction expenditures in accounts payable	$ 402.0	$ 723.0
Entergy Arkansas [Member]
Construction expenditures in accounts payable	33.5	35.6
Entergy Louisiana [Member]
Construction expenditures in accounts payable	239.7	507.9
Entergy Mississippi [Member]
Construction expenditures in accounts payable	13.8	26.5
Entergy New Orleans [Member]
Construction expenditures in accounts payable	4.0
Entergy Texas [Member]
Construction expenditures in accounts payable	35.1	73.1
System Energy [Member]
Construction expenditures in accounts payable	$ 34.5	$ 23.4

XML

Variable Interest Entities (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Variable Interest Entity [Line Items]
Assets	$ 59,833,526		$ 59,454,242
Entergy New Orleans [Member]
Variable Interest Entity [Line Items]
Assets	2,058,947		2,150,323
Entergy Louisiana [Member]
Variable Interest Entity [Line Items]
Assets	28,048,040		27,675,838
System Energy [Member]
Variable Interest Entity [Line Items]
Assets	$ 4,379,851		4,372,624
System Energy [Member] | Grand Gulf [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage	11.50%
Payments on lease, including interest	$ 8,600	$ 8,600
Entergy Arkansas [Member]
Variable Interest Entity [Line Items]
Assets	12,655,739		$ 12,565,119
Entergy Arkansas [Member] | AR Searcy Partnership, LLC
Variable Interest Entity [Line Items]
Assets	142,000
Ownership Interest in Partnership, Carrying Value	$ 113,000

XML

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,877,925	$ 2,844,838
Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	558,956	583,386
Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,265,972	1,107,644
Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	349,029	336,619
Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	198,272	169,335
Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	472,482	480,220
Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,655,776	2,538,420
Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	558,956	583,386
Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,237,237	1,079,663
Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	349,029	336,619
Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	154,646	139,148
Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	472,482	480,220
Natural Gas, US Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	72,361	58,168
Natural Gas, US Regulated [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Natural Gas, US Regulated [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	28,735	27,981
Natural Gas, US Regulated [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Natural Gas, US Regulated [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	43,626	30,187
Natural Gas, US Regulated [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Competitive Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	149,788	248,250
Residential [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	986,023	966,855
Residential [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	227,786	237,182
Residential [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	353,567	335,760
Residential [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	152,939	147,636
Residential [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	58,658	66,427
Residential [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	193,073	179,850
Commercial [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	634,626	572,676
Commercial [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	113,238	106,416
Commercial [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	257,591	224,649
Commercial [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	110,661	97,936
Commercial [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	45,572	47,799
Commercial [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	107,564	95,876
Industrial [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	743,634	597,652
Industrial [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	109,675	103,412
Industrial [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	451,954	347,009
Industrial [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	39,157	33,980
Industrial [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6,272	6,789
Industrial [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	136,576	106,462
Governmental [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	57,292	56,798
Governmental [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,460	4,256
Governmental [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	19,016	18,616
Governmental [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	12,000	10,543
Governmental [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15,033	16,380
Governmental [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6,783	7,003
Billed Retail [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,421,575	2,193,981
Billed Retail [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	455,159	451,266
Billed Retail [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,082,128	926,034
Billed Retail [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	314,757	290,095
Billed Retail [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	125,535	137,395
Billed Retail [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	443,996	389,191
Sales for Resale [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	128,959	205,075
Sales for Resale [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	70,414	110,085
Sales for Resale [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	107,701	80,428
Sales for Resale [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	21,641	40,311
Sales for Resale [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	26,540	4,696
Sales for Resale [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	17,644	74,073
Non-Customer [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	11,362	59,103
Non-Customer [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,811	2,452
Non-Customer [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,926	29,291
Non-Customer [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,294	2,263
Non-Customer [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,178	416
Non-Customer [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(607)	(573)
Non-Customer [Member] | Competitive Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,965	16,137
Other Electric [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	93,880	80,261
Other Electric [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	30,572	19,583
Other Electric [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	41,482	43,910
Other Electric [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10,337	3,950
Other Electric [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,393	(3,359)
Other Electric [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	11,449	17,529
Revenues from customers [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,644,414	2,479,317
Revenues from customers [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	556,145	580,934
Revenues from customers [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,231,311	1,050,372
Revenues from customers [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	346,735	334,356
Revenues from customers [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	153,468	138,732
Revenues from customers [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	473,089	480,793
Competitive Business Sales [Member] | Competitive Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 144,823	$ 232,113

XML

Revenue Recognition (Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	$ 31.5	$ 119.0	$ 68.6	$ 117.7
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	(5.9)	3.2
Accounts Receivable, Allowance for Credit Loss, Writeoff	(45.3)	(3.8)
Accounts Receivable, Allowance for Credit Loss, Recovery	14.1	1.9
Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	6.5	21.2	13.1	18.3
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	3.7	2.4
Accounts Receivable, Allowance for Credit Loss, Writeoff	(14.4)	(0.1)
Accounts Receivable, Allowance for Credit Loss, Recovery	4.1	0.6
Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	11.1	46.6	29.2	45.7
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	(6.1)	2.3
Accounts Receivable, Allowance for Credit Loss, Writeoff	(17.5)	(2.1)
Accounts Receivable, Allowance for Credit Loss, Recovery	5.5	0.7
Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	3.4	16.8	7.2	19.5
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	(0.9)	(2.2)
Accounts Receivable, Allowance for Credit Loss, Writeoff	(4.1)	(0.8)
Accounts Receivable, Allowance for Credit Loss, Recovery	1.2	0.3
Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	7.7	19.4	13.3	17.4
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	(2.4)	1.8
Accounts Receivable, Allowance for Credit Loss, Writeoff	(5.4)	0.0
Accounts Receivable, Allowance for Credit Loss, Recovery	2.2	0.2
Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	2.8	15.0	$ 5.8	$ 16.8
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	(0.2)	(1.1)
Accounts Receivable, Allowance for Credit Loss, Writeoff	(3.9)	(0.8)
Accounts Receivable, Allowance for Credit Loss, Recovery	$ 1.1	$ 0.1

XML

Label	Element	Value
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	$ 442,559,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	1,759,099,000
Entergy Louisiana [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	18,573,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	728,020,000
Entergy New Orleans [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	42,862,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	26,000
Entergy Texas [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	28,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	248,596,000
Entergy Mississippi [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	47,627,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	18,000
Entergy Arkansas [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	12,915,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	192,128,000
System Energy [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	89,201,000
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents	$ 242,469,000