10-Q

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__________________________________________________________________________________________

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, 2021

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) 10055 Grogans Mill Road 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

__________________________________________________________________________________________

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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

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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 30, 2021
Entergy Corporation	($0.01 par value)	200,659,948

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, 2020, 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	16
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	33
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	42
Note 7. Business Segment Information	46
Note 8. Risk Management and Fair Values	47
Note 9. Decommissioning Trust Funds	65
Note 10. Income Taxes	70
Note 11. Property, Plant, and Equipment	71
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	99

i

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	Page Number
Consolidated Statements of Comprehensive Income	100
Consolidated Statements of Cash Flows	101
Consolidated Balance Sheets	102
Consolidated Statements of Changes in Equity	104
Entergy Mississippi, LLC
Management’s Financial Discussion and Analysis	105
Income Statements	111
Statements of Cash Flows	113
Balance Sheets	114
Statements of Changes in Member’s Equity	116
Entergy New Orleans, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	117
Consolidated Income Statements	123
Consolidated Statements of Cash Flows	125
Consolidated Balance Sheets	126
Consolidated Statements of Changes in Member’s Equity	128
Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis	129
Consolidated Income Statements	137
Consolidated Statements of Cash Flows	139
Consolidated Balance Sheets	140
Consolidated Statements of Changes in Equity	142
System Energy Resources, Inc.
Management’s Financial Discussion and Analysis	143
Income Statements	149
Statements of Cash Flows	151
Balance Sheets	152
Statements of Changes in Common Equity	154
Part II. Other Information
Item 1. Legal Proceedings	155
Item 1A. Risk Factors	155
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	155
Item 5. Other Information	156
Item 6. Exhibits	158
Signature	161

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 those factors discussed or incorporated by reference in (a) Item 1A. Risk Factors in the Form 10-K and in this report, (b) 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;

•continuing long-term risks and uncertainties associated with the termination of the System Agreement in 2016, including the potential absence of federal authority to resolve certain issues among the Utility operating companies and their retail regulators;

•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 nuclear generating facilities and nuclear materials and fuel, including with respect to the planned or actual shutdown and sale of each of the nuclear generating facilities owned or operated by Entergy Wholesale Commodities, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and nuclear 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, emerging operating and industry issues, and 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;

•prices for power generated by Entergy’s merchant generating facilities and the ability to hedge, meet credit support requirements for hedges, sell power forward or otherwise reduce the market price risk associated with those facilities, including the Entergy Wholesale Commodities nuclear plants, especially in light of the planned shutdown and sale of each of these nuclear plants;

•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;

•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, and Hurricane Zeta), 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;

•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, a utility industry mutual insurance company, and industry self-insurance programs;

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

•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;

•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 the northern United States and events and circumstances that could influence economic conditions in those areas, including power prices, and the risk that anticipated load growth may not materialize;

•changes to federal income tax laws and regulations, including 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;

iv

FORWARD-LOOKING INFORMATION (Concluded)

•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, execute share repurchase programs, and fund investments and acquisitions;

•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 event or pandemic, such as the COVID-19 global pandemic, 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 shutdowns and sales of Indian Point 2, Indian Point 3, and 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;

•the potential for the factors listed herein to lead to the impairment of long-lived assets; and

•Entergy and its subsidiaries’ ability to successfully execute on their business strategies, including their ability to complete strategic transactions that Entergy 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, 2020 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
Independence	Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power, LLC

vi

DEFINITIONS (Continued)

Abbreviation or Acronym	Term
Indian Point 2	Unit 2 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2020
Indian Point 3	Unit 3 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 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)
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
Net MW in operation	Installed capacity owned and operated
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
Pilgrim	Pilgrim Nuclear Power Station (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in May 2019 and was sold in August 2019
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
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.

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

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic and its effects on Entergy’s business.

Hurricane Laura, Hurricane Delta, and Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of the Utility’s service territories in Louisiana, including New Orleans, Texas, and to a lesser extent, in Arkansas and Mississippi. See Note 2 to the financial statements herein for discussion of storm cost recovery filings made by Entergy Louisiana and Entergy Texas in April 2021. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for February 2021 for Entergy were approximately $720 million, including $145 million for Entergy Arkansas, $285 million for Entergy Louisiana, $65 million for Entergy Mississippi, $35 million for Entergy New Orleans, and $185 million for Entergy Texas. This compares to fuel and purchased power costs for February 2020 for Entergy of $245 million, including $40 million for Entergy Arkansas, $95 million for Entergy Louisiana, $35 million for Entergy Mississippi, $25 million for Entergy New Orleans, and $50 million for Entergy Texas. See Note 2 to the financial statements herein for discussion of storm cost recovery filings made by Entergy Louisiana and Entergy Texas in April 2021. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at the Utility operating companies.

1

Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Results of Operations

First Quarter 2021 Compared to First Quarter 2020

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the first quarter 2021 to the first quarter 2020 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)
2020 Net Income (Loss) Attributable to Entergy Corporation	$319,816	($110,975)	($90,127)	$118,714
Operating revenues	501,987	(84,330)	2	417,659
Fuel, fuel-related expenses, and gas purchased for resale	102,680	1,094	(10)	103,764
Purchased power	155,967	7,143	10	163,120
Other regulatory charges (credits) - net	39,958	—	—	39,958
Other operation and maintenance	36,589	(32,049)	162	4,702
Asset write-offs, impairments, and related charges	—	(1,822)	—	(1,822)
Taxes other than income taxes	(255)	(13,641)	304	(13,592)
Depreciation and amortization	37,052	(22,148)	(95)	14,809
Other income (deductions)	30,046	218,171	6,257	254,474
Interest expense	13,847	(1,106)	(3,013)	9,728
Other expenses	(3,239)	1,718	—	(1,521)
Income taxes	112,683	46,100	(21,647)	137,136
2021 Net Income (Loss) Attributable to Entergy Corporation	$356,567	$37,577	($59,579)	$334,565

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

First quarter 2020 results of operations include losses of $211 million (pre-tax) on Entergy Wholesale Commodities’ nuclear decommissioning trust fund investments reflecting the equity market decline in March 2020 associated with the COVID-19 pandemic. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments.

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 2021 to the first quarter 2020:

	Amount
	(In Millions)
2020 operating revenues	$2,095
Fuel, rider, and other revenues that do not significantly affect net income	323
Volume/weather	97
Retail electric price	96
Return of unprotected excess accumulated deferred income taxes to customers	(14)
2021 operating revenues	$2,597

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 volume/weather variance is primarily due to an increase of 990 GWh, or 4%, in billed electricity usage, including the effect of more favorable weather on residential sales, partially offset by a decrease in industrial usage and decreased demand from mid to small customers. The decrease in industrial usage is primarily due to decreased demand from existing customers in the chemicals and petroleum refining industries as a result of the COVID-19 pandemic and plant shutdowns and operational issues. The decrease in industrial usage is partially offset by an increase in demand from expansion projects, primarily in the transportation, metals, and chemicals industries. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

The retail electric price variance is primarily due to:

•increases in Entergy Louisiana’s formula rate plan revenues, including an interim increase effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station, an increase in the transmission recovery mechanism effective September 2020, and an interim increase effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center;

•increases in Entergy Mississippi’s formula rate plan rates effective with the first billing cycle of April 2020 and the implementation of a vegetation management rider effective with the April 2020 billing cycle;

•an increase in Entergy New Orleans’s formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020; and

•the implementation of the generation cost recovery rider effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021, 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.

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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 first quarter 2021, $41 million was returned to customers through reductions in operating revenues as compared to $27 million in first quarter 2020. 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.     

Billed electric energy sales for Utility for the three months ended March 31, 2021 and 2020 are as follows:

	2021	2020	% Change
	(GWh)
Residential	9,599	8,126	18
Commercial	6,134	6,244	(2)
Industrial	11,458	11,815	(3)
Governmental	579	595	(3)
Total retail	27,770	26,780	4
Sales for resale	4,299	3,117	38
Total	32,069	29,897	7

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 $332 million for the first quarter 2020 to $248 million for the first quarter 2021 primarily due to the shutdown of the Indian Point 2 plant in April 2020.

Following are key performance measures for Entergy Wholesale Commodities for the first quarters 2021 and 2020:

	2021	2020
Owned capacity (MW) (a)	2,246	3,274
GWh billed	4,413	6,757
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor	99%	99%
GWh billed	3,988	6,259
Average energy price ($/MWh)	$51.86	$47.42
Average capacity price ($/kW-month)	$0.23	$1.07

The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the first quarters 2021 and 2020.

(a)The reduction in owned capacity is due to the shutdown of the 1,028 MW Indian Point 2 plant in April 2020.

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Management's Financial Discussion and Analysis

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $566 million for the first quarter 2020 to $602 million for the first quarter 2021 primarily due to:

•lower nuclear insurance refunds of $13 million;

•an increase of $7 million in non-nuclear generation expenses due to higher expenses associated with plants placed in service, including the Lake Charles Power Station, which began commercial operation in March 2020, the New Orleans Power Station which began commercial operation in May 2020, the Washington Parish Energy Center purchased in November 2020, and the Montgomery County Power Station which began commercial operation in January 2021;

•an increase of $7 million in vegetation maintenance costs; and

•an increase of $5 million in nuclear generation expenses primarily due to spending on sanitation and social distancing protocols as a result of COVID-19.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station and the Montgomery County Power Station.

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 and $29 million recorded in first quarter 2020, at Entergy Louisiana, due to a settlement with the IRS related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers. See Note 2 to the financial statements herein and in the Form 10-K for discussion of Entergy Arkansas’s 2020 formula rate plan filing. See Note 3 to the financial statements in the Form 10-K for further discussion of the settlement and savings obligation.

Other income increased primarily due to changes in decommissioning trust fund activity, partially offset by a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project.

Interest expense increased primarily due to:

•the issuance by Entergy Louisiana of $350 million of 2.90% Series mortgage bonds in March 2020;

•the issuance by Entergy Louisiana of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;

•the issuance 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; and

•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project.

The increase was partially offset by the repayments by Entergy Louisiana of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020.

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Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $131 million for the first quarter 2020 to $99 million for the first quarter 2021 primarily due to:

•a decrease of $28 million primarily resulting from the absence of expenses from the Indian Point 2 plant after it was shut down in April 2020; and

•a decrease of $6 million in severance and retention expenses. Severance and retention expenses were incurred in 2021 and 2020 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 of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses resulting from management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet.

Taxes other than income taxes decreased primarily due to lower payroll taxes and lower ad valorem taxes.

Depreciation and amortization expenses decreased primarily due to:

•the absence of depreciation expense from the Indian Point 2 plant, after it was shut down in April 2020; and

•the effect of recording in 2021 a final judgment to resolve claims in the Palisades damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included $9 million of spent nuclear fuel storage costs previously recorded as depreciation expense. See Note 1 to the financial statements herein for discussion of the spent nuclear fuel litigation.

Other income increased primarily due to losses on decommissioning trust fund investments in the first quarter 2020. These losses reflected the equity market decline in March 2020 associated with the COVID-19 pandemic. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments.

Income Taxes

The effective income tax rate was 16.3% 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, 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.

The effective income tax rate was (136.6%) for the first quarter 2020. The difference in the effective income tax rate for the first quarter 2020 versus the federal statutory rate of 21% was primarily due to the settlement with the IRS on the treatment of funds received in conjunction with the Louisiana Act 55 financing of Hurricane Isaac storm costs, permanent differences related to income tax deductions for stock-based compensation, amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for discussion of the IRS settlement and the income tax deductions for stock-based compensation. 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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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 remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet.  Following are updates to that discussion.

Planned Shutdown and Sale of Indian Point 2 and Indian Point 3

As discussed in the Form 10-K, in April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 has been shut down and defueled, to a Holtec subsidiary for decommissioning the plants. The sale will include the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units.

In November 2019, Entergy and Holtec submitted a license transfer application to the NRC. The NRC issued an order approving the application in November 2020, subject to the NRC’s authority to condition, revise, or rescind the approval order based on the resolution of four pending hearing requests. In January 2021 the NRC issued an order denying all four hearing requests challenging the license transfer application. In January 2021, New York State filed a petition for review with the D.C. Circuit asking the court to vacate the NRC’s January 2021 order denying the State’s hearing request, as well as the NRC’s November 2020 order approving the license transfers. In January 2021 the D.C. Circuit issued a scheduling order, setting deadlines for initial procedural filings in March 2021. In March 2021 additional parties also filed petitions for review with the D.C. Circuit seeking review of the same NRC orders. In March 2021 the court consolidated all of the appeals into the same proceeding. The court has yet to issue a scheduling order for briefing.

In November 2019, Entergy and Holtec also submitted a petition to the New York State Public Service Commission (NYPSC) seeking an order from the NYPSC disclaiming jurisdiction or abstaining from review of the transaction or, alternatively, approving the transaction. Closing is also conditioned on obtaining from the New York State Department of Environmental Conservation an agreement related to Holtec’s decommissioning plan as being consistent with applicable standards. In April 2021, Entergy and Holtec filed a joint settlement proposal with the NYPSC that resolves all issues among all parties. These issues include financial assurance, site restoration, financial reporting, continued funding for state and local emergency management and response activities, a memorandum of understanding with local taxing jurisdictions, and the dismissal of the federal appeals described in the preceding paragraph. The NYPSC is expected to take action on the joint settlement proposal at its May 13, 2021 meeting.

Indian Point 2 permanently ceased operations on April 30, 2020 and Indian Point 3 permanently ceased operations on April 30, 2021. The transaction is targeted to close in May 2021, following the defueling of Indian Point 3. The Indian Point transaction is expected to result in a $285 million net loss based on the difference between Entergy’s adjusted net investment in the subsidiaries at closing and the sale price net of agreed adjustments. The primary variables in the ultimate loss that Entergy will incur are the values of the nuclear decommissioning trusts 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.

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 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.

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In December 2020, Entergy and Holtec submitted a license transfer application to the NRC requesting approval to transfer the Palisades and Big Rock Point licenses from Entergy to Holtec. The NRC has indicated that it expects to complete its review of the application by January 2022. In February 2021 several parties filed with the NRC petitions to intervene and requests for hearing challenging the license transfer application. In March 2021, Entergy and Holtec filed answers opposing the petitions to intervene and hearing requests, and the petitioners filed replies. In March 2021 an additional party also filed a petition to intervene and request for hearing. Entergy and Holtec filed an answer to the March 2021 petition in April 2021.

Subject to the conditions discussed in the Form 10-K, the transaction is expected to close by the end of 2022. As of March 31, 2021, Entergy’s adjusted net investment in Palisades was $30 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 Entergy Wholesale Commodities Strategic 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 $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 2022. In addition, Entergy Wholesale Commodities incurred impairment charges of $3 million primarily related to expenditures for capital assets for the three months ended March 31, 2021. These costs were charged to expense as incurred as a result of the impaired value of certain of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business.

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, 2021 is primarily due to the net issuance of debt in 2021.

	March 31, 2021		December 31, 2020
Debt to capital	69.6	%	68.3	%
Effect of excluding securitization bonds	(0.1	%)	(0.2	%)
Debt to capital, excluding securitization bonds (a)	69.5	%	68.1	%
Effect of subtracting cash	(1.5	%)	(1.7	%)
Net debt to net capital, excluding securitization bonds (a)	68.0	%	66.4	%

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

As of March 31, 2021, 22.2% of the debt outstanding is at the parent company, Entergy Corporation, 77.3% 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

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Management's Financial Discussion and Analysis

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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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. One such difference is that it excludes the effects, among other things, of certain impairments related to the Entergy Wholesale Commodities nuclear generation assets.  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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the 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 Registrant Subsidiaries’ credit facilities.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of March 31, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Certain of the Utility operating companies have a total of $72 million in storm reserve escrow accounts at 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 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. Entergy has not issued any shares or entered into any forward sale agreements under this program.

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Management's Financial Discussion and Analysis

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 2021 through 2023. Following are updates to that discussion.

Liberty County Solar Facility

In September 2020, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to acquire the 100 MW Liberty County Solar Facility and a determination that Entergy Texas’s acquisition of the facility through a tax equity partnership is in the public interest. In its preliminary order, the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s use of a tax equity partnership is in the public interest. In March 2021 intervenors and PUCT staff filed testimony, and Entergy Texas filed rebuttal testimony in April 2021. A hearing on the merits was held in April 2021. Post-hearing briefs and reply briefs are due in May 2021. Closing is expected to occur in 2023.

Hardin County Peaking Facility

In April 2020, Entergy Texas and East Texas Electric Cooperative, Inc. filed a joint report and application seeking PUCT approvals related to two transactions: (1) Entergy Texas’s acquisition of the Hardin County Peaking Facility from East Texas Electric Cooperative, Inc.; and (2) Entergy Texas’s sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. The two transactions, currently expected to close in June 2021, are interdependent. In October 2020, Entergy Texas filed an unopposed settlement agreement supporting approval of the transactions. Key provisions of the settlement include: Entergy Texas will propose to depreciate its investment in Hardin County Peaking Facility through the end of 2041; Entergy Texas’s recovery of its investment in Hardin County Peaking Facility will be capped at approximately $36 million; and Entergy Texas will not seek recovery of an acquisition adjustment, if any, or transaction costs for either transaction. The settlement was approved by the PUCT in April 2021.

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 2021 meeting, the Board declared a dividend of $0.95 per share, which is the same quarterly dividend per share that Entergy has paid since the third quarter 2020.

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Management's Financial Discussion and Analysis

Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the three months ended March 31, 2021 and 2020 were as follows:

	2021	2020
	(In Millions)
Cash and cash equivalents at beginning of period	$1,759	$426
Cash flow provided by (used in):
Operating activities	(49)	659
Investing activities	(1,513)	(1,045)
Financing activities	1,546	1,424
Net increase (decrease) in cash and cash equivalents	(16)	1,038
Cash and cash equivalents at end of period	$1,743	$1,464

Operating Activities

Entergy’s operating activities used $49 million of cash for the three months ended March 31, 2021 compared to providing $659 million of cash for the three months ended March 31, 2020 primarily due to the following activity:

•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•an increase of approximately $200 million in storm spending;

•an increase of $92 million in pension contributions in 2021 as compared to the same period in 2020. 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;

•income tax payments of $9 million in 2021 compared to income tax refunds of $23 million in 2020. Entergy had net income tax payments in 2021 as a result of amended Mississippi state tax returns filed, offset by federal income tax refunds received associated with the completion of the 2014-2015 IRS audit. Entergy had income tax refunds in 2020 as a result of an overpayment on a prior year state income tax return;

•a decrease of $18 million of nuclear insurance refunds; and

•the effect of more favorable weather on billed Utility sales in 2021.

Investing Activities

Net cash flow used in investing activities increased $468 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to:

•an increase of $524 million in distribution construction expenditures primarily due to storm spending in 2021. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•an increase of $138 million in transmission construction expenditures primarily due to storm spending in 2021, partially offset by a lower scope of work on projects performed in 2021 as compared to 2020. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts; and

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•a decrease of $46 million in proceeds received from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. 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 increase was partially offset by:

•a decrease of $84 million of non-nuclear generation construction expenditures primarily due to higher spending in 2020 on the Montgomery County Power Station and Lake Charles Power Station projects;

•a decrease of $41 million in nuclear construction expenditures primarily due to decreased spending on various projects in 2021;

•a decrease of $37 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;

•a decrease of $32 million in decommissioning trust fund investment activity;

•a decrease of $26 million in information technology expenditures primarily due to decreased spending on various technology projects; and

•$25 million in plant upgrades for the Choctaw Generating Station in March 2020. See Note 14 to the financial statements in the Form 10-K for further discussion of the Choctaw Generating Station purchase.

Financing Activities

Net cash flow provided by financing activities increased $122 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to long-term debt activity providing approximately $2,330 million of cash in 2021 compared to providing approximately $1,581 million of cash in 2020.

The increase was partially offset by:

•an increase of $595 million in net repayments of commercial paper in 2021 compared to 2020; and

•a decrease of $39 million in treasury stock issuances in 2021 due to a larger amount of previously repurchased Entergy Corporation common stock issued in 2020 to satisfy stock option exercises.

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.

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.

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Market and Credit Risk Sensitive Instruments

Commodity Price Risk

Power Generation

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy in the day ahead or spot markets.  Entergy Wholesale Commodities also sells unforced capacity, which allows load-serving entities to meet specified reserve and related requirements placed on them by the ISOs in their respective areas.  Entergy Wholesale Commodities’ forward physical power contracts consist of contracts to sell energy only, contracts to sell capacity only, and bundled contracts in which it sells both capacity and energy.  While the terminology and payment mechanics vary in these contracts, each of these types of contracts requires Entergy Wholesale Commodities to deliver MWh of energy, make capacity available, or both. In addition to its forward physical power contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to manage forward commodity price risk. The sensitivities may not reflect the total maximum upside potential from higher market prices. The information contained in the following table represents projections at a point in time and will vary over time based on numerous factors, such as future market prices, contracting activities, and generation. Following is a summary of Entergy Wholesale Commodities’ current forward capacity and generation contracts as well as total revenue projections based on market prices as of March 31, 2021 (2021 represents the remainder of the year):

Entergy Wholesale Commodities Nuclear Portfolio

	2021	2022
Energy
Percent of planned generation under contract (a):
Unit-contingent (b)	98%	99%
Planned generation (TWh) (c) (d)	5.8	2.8
Average revenue per MWh on contracted volumes:
Expected based on market prices as of March 31, 2021	$56.4	$47.1
Capacity
Percent of capacity sold forward (e):
Bundled capacity and energy contracts (f)	86%	98%
Capacity contracts (g)	13%	—%
Total	99%	98%
Planned net MW in operation (average) (d)	1,158	338
Average revenue under contract per kW per month (applies to capacity contracts only)	$0.1	$—
Total Energy and Capacity Revenues (h)
Expected sold and market total revenue per MWh	$55.8	$46.8
Sensitivity: -/+ $10 per MWh market price change	$55.7-$56.0	$46.7-$47.0

(a)Percent of planned generation output sold under contracts.

(b)Transaction under which power is supplied from a specific generation asset; if the asset is not operating, the seller is generally not liable to the buyer for any damages. Certain unit-contingent sales include a guarantee

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of availability. Availability guarantees provide for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold. All of Entergy’s outstanding guarantees of availability provide for dollar limits on Entergy’s maximum liability under such guarantees.

(c)Amount of output expected to be generated by Entergy Wholesale Commodities nuclear resources considering plant operating characteristics.

(d)Assumes the shutdown of Indian Point 3 on April 30, 2021 and planned shutdown of Palisades on May 31, 2022. For a discussion regarding the shutdown of the Indian Point 3 plant and planned shutdown of the Palisades plant, see “Entergy Wholesale Commodities Exit from the Merchant Power Business” above.

(e)Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.

(f)A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.

(g)A contract for the sale of an installed capacity product in a regional market.

(h)Excludes non-cash revenue from the amortization of the Palisades below-market purchased power agreement, mark-to-market activity, and service revenues.

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 Entergy subsidiary is required to provide credit support based upon the difference between the current market prices and contracted power prices in the regions where Entergy Wholesale Commodities sells power. 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, 2021, based on power prices at that time, Entergy had liquidity exposure of $51 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $7 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, 2021, 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, 2020, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by $7 million for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.

As of March 31, 2021, substantially all of the credit exposure associated with the planned energy output under contract for Entergy Wholesale Commodities nuclear plants 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. Following are updates to the discussion in the Form 10-K.

NRC Reactor Oversight Process

As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of associated costs. Nuclear generating plants owned and operated by Entergy’s Utility and Entergy Wholesale Commodities businesses are currently in Column 1, except for Grand Gulf, which is in Column 3.

14

Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.

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.

15

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands, Except Share Data)
OPERATING REVENUES
Electric	$2,538,420	$2,050,638
Natural gas	58,168	43,976
Competitive businesses	248,250	332,565
TOTAL	2,844,838	2,427,179
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	501,167	397,403
Purchased power	379,734	216,614
Nuclear refueling outage expenses	43,739	50,218
Other operation and maintenance	706,786	702,084
Asset write-offs, impairments, and related charges	3,273	5,095
Decommissioning	98,642	93,684
Taxes other than income taxes	156,702	170,294
Depreciation and amortization	414,519	399,710
Other regulatory charges (credits) - net	32,279	(7,679)
TOTAL	2,336,841	2,027,423
OPERATING INCOME	507,997	399,756
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	14,577	35,953
Interest and investment income (loss)	143,315	(216,853)
Miscellaneous - net	(60,929)	23,389
TOTAL	96,963	(157,511)
INTEREST EXPENSE
Interest expense	205,886	205,589
Allowance for borrowed funds used during construction	(6,013)	(15,444)
TOTAL	199,873	190,145
INCOME BEFORE INCOME TAXES	405,087	52,100
Income taxes	65,942	(71,194)
CONSOLIDATED NET INCOME	339,145	123,294
Preferred dividend requirements of subsidiaries	4,580	4,580
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$334,565	$118,714
Earnings per average common share:
Basic	$1.67	$0.59
Diluted	$1.66	$0.59
Basic average number of common shares outstanding	200,525,549	199,790,016
Diluted average number of common shares outstanding	201,059,665	200,901,349
See Notes to Financial Statements.

16

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
Net Income	$339,145	$123,294
Other comprehensive income (loss)
Cash flow hedges net unrealized loss (net of tax benefit of $7,869 and $5,777)	(29,580)	(21,710)
Pension and other postretirement liabilities (net of tax expense of $6,314 and $15,076)	22,967	53,899
Net unrealized investment gain (loss) (net of tax expense (benefit) of ($25,581) and $8,743)	(44,687)	15,744
Other comprehensive income (loss)	(51,300)	47,933
Comprehensive Income	287,845	171,227
Preferred dividend requirements of subsidiaries	4,580	4,580
Comprehensive Income Attributable to Entergy Corporation	$283,265	$166,647
See Notes to Financial Statements.

17

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING ACTIVITIES
Consolidated net income	$339,145	$123,294
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	580,571	568,596
Deferred income taxes, investment tax credits, and non-current taxes accrued	240,431	(31,405)
Asset write-offs, impairments, and related charges	3,278	4,962
Changes in working capital:
Receivables	(52,690)	70,357
Fuel inventory	26,878	(15,389)
Accounts payable	(175,651)	(127,727)
Taxes accrued	(231,182)	(44,241)
Interest accrued	(3,778)	(4,791)
Deferred fuel costs	(353,099)	30,560
Other working capital accounts	(43,582)	(21,758)
Changes in provisions for estimated losses	(60,923)	(35,829)
Changes in other regulatory assets	89,910	99,275
Changes in other regulatory liabilities	(14,464)	(450,905)
Changes in pension and other postretirement liabilities	(166,733)	(113,071)
Other	(227,676)	607,132
Net cash flow provided by (used in) operating activities	(49,565)	659,060
INVESTING ACTIVITIES
Construction/capital expenditures	(1,552,103)	(1,043,608)
Allowance for equity funds used during construction	14,577	35,953
Nuclear fuel purchases	(47,916)	(85,334)
Payment for purchase of assets	—	(24,633)
Changes in securitization account	(1,304)	(70)
Payments to storm reserve escrow account	(10)	(1,557)
Receipts from storm reserve escrow account	44,205	40,589
Decrease in other investments	12,521	2,265
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	15,735	62,162
Proceeds from nuclear decommissioning trust fund sales	3,225,510	687,487
Investment in nuclear decommissioning trust funds	(3,224,487)	(718,741)
Net cash flow used in investing activities	(1,513,272)	(1,045,487)
See Notes to Financial Statements.

18

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt	3,676,242	3,195,345
Treasury stock	979	39,964
Retirement of long-term debt	(1,346,172)	(1,614,578)
Changes in credit borrowings and commercial paper - net	(599,860)	(4,911)
Other	10,380	(756)
Dividends paid:
Common stock	(190,595)	(185,763)
Preferred stock	(4,580)	(4,763)
Net cash flow provided by financing activities	1,546,394	1,424,538
Net increase (decrease) in cash and cash equivalents	(16,443)	1,038,111
Cash and cash equivalents at beginning of period	1,759,099	425,722
Cash and cash equivalents at end of period	$1,742,656	$1,463,833
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$202,451	$203,466
Income taxes	$9,015	($23,063)
See Notes to Financial Statements.

19

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$67,574	$128,851
Temporary cash investments	1,675,082	1,630,248
Total cash and cash equivalents	1,742,656	1,759,099
Accounts receivable:
Customer	883,352	833,478
Allowance for doubtful accounts	(119,027)	(117,794)
Other	158,838	135,208
Accrued unbilled revenues	415,253	434,835
Total accounts receivable	1,338,416	1,285,727
Deferred fuel costs	226,619	4,380
Fuel inventory - at average cost	146,056	172,934
Materials and supplies - at average cost	972,771	962,185
Deferred nuclear refueling outage costs	182,721	179,150
Prepayments and other	179,315	196,424
TOTAL	4,788,554	4,559,899
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	7,339,088	7,253,215
Non-utility property - at cost (less accumulated depreciation)	355,819	343,328
Other	169,094	214,222
TOTAL	7,864,001	7,810,765
PROPERTY, PLANT, AND EQUIPMENT
Electric	60,901,229	59,696,443
Natural gas	621,682	610,768
Construction work in progress	1,311,997	2,012,030
Nuclear fuel	591,124	601,281
TOTAL PROPERTY, PLANT, AND EQUIPMENT	63,426,032	62,920,522
Less - accumulated depreciation and amortization	24,403,999	24,067,745
PROPERTY, PLANT, AND EQUIPMENT - NET	39,022,033	38,852,777
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $92,585 as of March 31, 2021 and $119,238 as of December 31, 2020)	5,986,639	6,076,549
Deferred fuel costs	240,555	240,422
Goodwill	377,172	377,172
Accumulated deferred income taxes	56,068	76,289
Other	332,606	245,339
TOTAL	6,993,040	7,015,771
TOTAL ASSETS	$58,667,628	$58,239,212
See Notes to Financial Statements.

20

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$629,019	$1,164,015
Notes payable and commercial paper	1,027,629	1,627,489
Accounts payable	1,697,206	2,739,437
Customer deposits	391,032	401,512
Taxes accrued	209,829	441,011
Interest accrued	198,013	201,791
Deferred fuel costs	22,386	153,113
Pension and other postretirement liabilities	63,752	61,815
Current portion of unprotected excess accumulated deferred income taxes	65,056	63,683
Other	207,984	206,640
TOTAL	4,511,906	7,060,506
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	4,568,106	4,361,772
Accumulated deferred investment tax credits	217,888	212,494
Regulatory liability for income taxes-net	1,465,852	1,521,757
Other regulatory liabilities	2,363,919	2,323,851
Decommissioning and asset retirement cost liabilities	6,528,450	6,469,452
Accumulated provisions	181,912	242,835
Pension and other postretirement liabilities	2,684,343	2,853,013
Long-term debt (includes securitization bonds of $146,881 as of March 31, 2021 and $174,635 as of December 31, 2020)	24,075,456	21,205,761
Other	798,210	807,219
TOTAL	42,884,136	39,998,154
Commitments and Contingencies
Subsidiaries' preferred stock without sinking fund	219,410	219,410
EQUITY
Common stock, $.01 par value, authorized 500,000,000 shares; issued 270,035,180 shares in 2021 and 2020	2,700	2,700
Paid-in capital	6,520,052	6,549,923
Retained earnings	10,041,152	9,897,182
Accumulated other comprehensive loss	(500,507)	(449,207)
Less - treasury stock, at cost (69,402,016 shares in 2021 and 69,790,346 shares in 2020)	5,046,221	5,074,456
Total common shareholders' equity	11,017,176	10,926,142
Subsidiaries' preferred stock without sinking fund	35,000	35,000
TOTAL	11,052,176	10,961,142
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$58,667,628	$58,239,212
See Notes to Financial Statements.

21

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
		Common Shareholders’ Equity
	Subsidiaries’ Preferred Stock	Common Stock	Treasury Stock	Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Loss	Total
	(In Thousands)
Balance at December 31, 2019	$35,000	$2,700	($5,154,150)	$6,564,436	$9,257,609	($446,920)	$10,258,675
Implementation of accounting standards	—	—	—	—	(419)	—	(419)
Balance at January 1, 2020	35,000	2,700	(5,154,150)	6,564,436	9,257,190	(446,920)	10,258,256
Consolidated net income (a)	4,580	—	—	—	118,714	—	123,294
Other comprehensive income	—	—	—	—	—	47,933	47,933
Common stock issuances related to stock plans	—	—	73,580	(53,753)	—	—	19,827
Common stock dividends declared	—	—	—	—	(185,763)	—	(185,763)
Preferred dividend requirements of subsidiaries (a)	(4,580)	—	—	—	—	—	(4,580)
Balance at March 31, 2020	$35,000	$2,700	($5,080,570)	$6,510,683	$9,190,141	($398,987)	$10,258,967

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
(a) Consolidated net income and preferred dividend requirements of subsidiaries for first quarter 2021 and first quarter 2020 each includes $4.1 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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

24

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base,

26

Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

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Notes to Financial Statements

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

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Notes to Financial Statements

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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,
	2021			2020
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$334.6	200.5	$1.67	$118.7	199.8	$0.59
Average dilutive effect of:
Stock options		0.4	(0.01)		0.7	—
Other equity plans		0.2	—		0.4	—
Diluted earnings per share	$334.6	201.1	$1.66	$118.7	200.9	$0.59

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.0 million for the three months ended March 31, 2021 and approximately 0.5 million for the three months ended March 31, 2020.

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 $0.95 for the three months ended March 31, 2021 and $0.93 for the three months ended March 31, 2020.

Treasury Stock

During the three months ended March 31, 2021, Entergy Corporation issued 388,330 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, 2021.

Retained Earnings

On April 12, 2021, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95 per share, payable on June 1, 2021, to holders of record as of May 6, 2021.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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, 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 for the three months ended March 31, 2020 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, 2020	$84,206	($557,072)	$25,946	($446,920)
Other comprehensive income (loss) before reclassifications	52,846	34,349	17,713	104,908
Amounts reclassified from accumulated other comprehensive income (loss)	(74,556)	19,550	(1,969)	(56,975)
Net other comprehensive income (loss) for the period	(21,710)	53,899	15,744	47,933
Ending balance, March 31, 2020	$62,496	($503,173)	$41,690	($398,987)

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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, 2021 and 2020:

	Pension and Other Postretirement Liabilities
	2021	2020
	(In Thousands)
Beginning balance, January 1,	$4,327	$4,562
Other comprehensive income (loss) before reclassifications	—	10,050
Amounts reclassified from accumulated other comprehensive income (loss)	(407)	(583)
Net other comprehensive income (loss) for the period	(407)	9,467
Ending balance, March 31,	$3,920	$14,029

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$39,367	$94,423	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	39,319	94,375
Income taxes	(8,257)	(19,819)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	$31,062	$74,556
Pension and other postretirement liabilities
Amortization of prior-service credit	$5,248	$3,719	(a)
Amortization of loss	(34,529)	(27,318)	(a)
Total amortization	(29,281)	(23,599)
Income taxes	6,314	4,049	Income taxes
Total amortization (net of tax)	($22,967)	($19,550)
Net unrealized investment gain (loss)
Realized gain (loss)	($972)	$3,116	Interest and investment income
Income taxes	358	(1,147)	Income taxes
Total realized investment gain (loss) (net of tax)	($614)	$1,969
Total reclassifications for the period (net of tax)	$7,481	$56,975

(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

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Notes to Financial Statements

details.

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,230	$1,089	(a)
Amortization of loss	(679)	(301)	(a)
Total amortization	551	788
Income taxes	(144)	(205)	Income taxes
Total amortization (net of tax)	407	583
Total reclassifications for the period (net of tax)	$407	$583

(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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

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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, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 508,704 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2021 with a fair value of $12.27 per option.  As of March 31, 2021, there were options on 2,890,582 shares of common stock outstanding with a weighted-average exercise price of $90.75.  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, 2021.  The aggregate intrinsic value of the stock options outstanding as of March 31, 2021 was $41.6 million.

The following table includes financial information for outstanding stock options for the three months ended March 31, 2021 and 2020:

	2021	2020
	(In Millions)
Compensation expense included in Entergy’s net income	$1.0	$1.0
Tax benefit recognized in Entergy’s 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 2021 the Board approved and Entergy granted 392,382 restricted stock awards and 203,983 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on January 28, 2021 and were valued at $95.87 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, Entergy Corporation is replacing the cumulative adjusted earnings per share metric with a credit measure – adjusted funds from operations/debt ratio for the 2021-2023 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 28, 2021 and eighty percent were valued at $110.74 per share based on various factors, primarily market conditions; and twenty percent were valued at $95.87 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.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The following table includes financial information for other outstanding equity awards for the three months ended March 31, 2021 and 2020:

	2021	2020
	(In Millions)
Compensation expense included in Entergy’s net income	$10.8	$9.4
Tax benefit recognized in Entergy’s net income	$2.7	$2.4
Compensation cost capitalized as part of fixed assets and materials and supplies	$4.0	$3.4

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Total restructuring charges for the first quarters of 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

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Notes to Financial Statements

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

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Notes to Financial Statements

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings.

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Notes to Financial Statements

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

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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, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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.

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Notes to Financial Statements

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 other than those instruments held by the Entergy Wholesale Commodities business 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.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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

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Notes to Financial Statements

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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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.

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Notes to Financial Statements

(b)The decommissioning trust funds fair values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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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Notes to Financial Statements

Entergy Arkansas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

61

Entergy Corporation and Subsidiaries

Notes to Financial Statements

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

62

Entergy Corporation and Subsidiaries

Notes to Financial Statements

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

63

Entergy Corporation and Subsidiaries

Notes to Financial Statements

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

64

Entergy Corporation and Subsidiaries

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, Indian Point 1, Indian Point 2, Indian Point 3, 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. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized 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, 2021 on equity securities still held as of March 31, 2021 were $200 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$3,436	$102	$43
2020
Debt Securities	$2,617	$197	$3

The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of March 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $3,376 million as of March 31, 2021 and $2,423 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.59%, an average duration of approximately 5.98 years, and an average maturity of approximately 8.45 years.

65

Entergy Corporation and Subsidiaries

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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,748	$43	$187	$3
More than 12 months	3	—	2	—
Total	$1,751	$43	$189	$3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($4)
1 year - 5 years	1,027	672
5 years - 10 years	1,257	852
10 years - 15 years	492	377
15 years - 20 years	128	144
20 years+	532	576
Total	$3,436	$2,617

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $524 million and $400 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $11 million and $14 million, respectively, and gross losses of $11 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2021 were $631 million for Indian Point 1, $760 million for Indian Point 2, $970 million for Indian Point 3, and $545 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

66

Entergy Corporation and Subsidiaries

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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$425.9	$13.2	$6.8
2020
Debt Securities	$447.9	$27.7	$0.3

The amortized cost of available-for-sale debt securities was $419.5 million as of March 31, 2021 and $420.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.42%, an average duration of approximately 6.40 years, and an average maturity of approximately 7.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $45.2 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$139.1	$6.8	$29.9	$0.3
More than 12 months	—	—	—	—
Total	$139.1	$6.8	$29.9	$0.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	84.7	113.1
5 years - 10 years	179.2	189.8
10 years - 15 years	100.8	81.4
15 years - 20 years	26.7	28.5
20 years+	34.5	35.1
Total	$425.9	$447.9

67

Entergy Corporation and Subsidiaries

Notes to Financial Statements

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $13.8 million and $48.6 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $0.8 million and $4.5 million, respectively, and gross losses of $0.1 million and $0.2 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$632.8	$31.2	$4.6
2020
Debt Securities	$632.2	$51.3	$0.5

The amortized cost of available-for-sale debt securities was $606.3 million as of March 31, 2021 and $581.4 million as of December 31, 2020.  As of March 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.25%, an average duration of approximately 6.59 years, and an average maturity of approximately 11.56 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $64.9 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$171.7	$4.6	$36.4	$0.5
More than 12 months	2.3	—	0.8	—
Total	$174.0	$4.6	$37.2	$0.5

68

Entergy Corporation and Subsidiaries

Notes to Financial Statements

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	89.3	117.0
5 years - 10 years	186.0	159.4
10 years - 15 years	113.7	101.2
15 years - 20 years	63.4	66.9
20 years+	180.4	187.7
Total	$632.8	$632.2

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $108.4 million and $67.4 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $3.3 million and $2.9 million, respectively, and gross losses of $3.2 million and $0.6 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$406.4	$14.3	$5.0
2020
Debt Securities	$427.7	$30.0	$0.8

The amortized cost of available-for-sale debt securities was $397 million as of March 31, 2021 and $398.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.36%, an average duration of approximately 6.31 years, and an average maturity of approximately 9.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $43.1 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.

69

Entergy Corporation and Subsidiaries

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, 2021 and December 31, 2020:

		March 31, 2021		December 31, 2020
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$157.5	$5.0	$28.9	$0.8
More than 12 months		—	—	—	—
Total		$157.5	$5.0	$28.9	$0.8

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($1.1)
1 year - 5 years	136.2	134.7
5 years - 10 years	120.4	141.5
10 years - 15 years	35.1	31.5
15 years - 20 years	4.5	5.3
20 years+	110.2	115.8
Total	$406.4	$427.7

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $74.1 million and $92 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $1.2 million and $1.7 million, respectively, and gross losses of $1.6 million and $0.2 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, 2021 and December 31, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $6.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021 and 2020.

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.

70

Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy.

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

71

Entergy Corporation and Subsidiaries

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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

72

Entergy Corporation and Subsidiaries

Notes to Financial Statements

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

73

Entergy Corporation and Subsidiaries

Notes to Financial Statements

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, 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

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 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, 2021, 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, 2021 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

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Arkansas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Arkansas were approximately $145 million in February 2021 compared to approximately $40 million in February 2020. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Arkansas.

In March 2021 the APSC opened an investigation into Arkansas utilities’ preparation, response, operational performance, and communication regarding the February 2021 extreme weather events. In April 2021, the Arkansas Attorney General notified utilities of its intent to conduct an investigation into the fuel costs that were charged during the February 2021 winter storms, specifically, whether there was price gouging by suppliers.

Results of Operations

Net Income

Net income increased $48.4 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 volume/weather, partially offset by a higher effective income tax rate.

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2021 to the first quarter 2020:

	Amount
	(In Millions)
2020 operating revenues	$481.9
Fuel, rider, and other revenues that do not significantly affect net income	63.4
Volume/weather	35.9
Return of unprotected excess accumulated deferred income taxes to customers	5.1
Retail electric price	(2.9)
2021 operating revenues	$583.4

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.

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Management's Financial Discussion and Analysis

The volume/weather variance is primarily due to an increase of 474 GWh, or 9%, in billed electricity usage, including the effect of more favorable weather on residential sales and increased industrial usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the metals industry.

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 first quarter 2021, $8 million was returned to customers as compared to $13.1 million in first quarter 2020. There is no effect on net income as the reduction in operating revenues in each period 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.

Billed electric energy sales for Entergy Arkansas for the three months ended March 31, 2021 and 2020 are as follows:

	2021	2020	% Change
	(GWh)
Residential	2,470	2,075	19
Commercial	1,266	1,284	(1)
Industrial	1,908	1,811	5
Governmental	54	54	—
Total retail	5,698	5,224	9
Sales for resale:
Associated companies	597	403	48
Non-associated companies	2,030	1,146	77
Total	8,325	6,773	23

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

Other Income Statement Variances

Other operation and maintenance expenses increased primarily due to lower nuclear insurance refunds of $5.8 million, partially offset by a decrease of $2.4 million in nuclear generation expenses primarily due to lower nuclear labor costs, including contract labor.

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

Other regulatory charges (credits) - net in the first quarter 2021 included the reversal 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 herein and in the Form 10-K for discussion of the 2020 formula rate plan filing.

Other income increased primarily due to changes in decommissioning trust fund investment activity.

Income Taxes

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,

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Management's Financial Discussion and Analysis

partially offset by state income taxes. See Note 10 to the financial statements herein and Note 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.

The effective income tax rate was (17.6%) for the first quarter 2020. The difference in the effective income tax rate for the first quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, permanent differences related to income tax deductions for stock-based compensation, 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 Note 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. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Cash and cash equivalents at beginning of period	$192,128	$3,519
Cash flow provided by (used in):
Operating activities	91,573	209,674
Investing activities	(162,611)	(190,551)
Financing activities	2,690	114,850
Net increase (decrease) in cash and cash equivalents	(68,348)	133,973
Cash and cash equivalents at end of period	$123,780	$137,492

Operating Activities

Net cash flow provided by operating activities decreased $118.1 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to:

•lower collections of receivables from customers, in part due to the COVID-19 pandemic;

•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•$25 million in proceeds received from the DOE in 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation; and

•an increase of $11.2 million in pension contributions 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.

The decrease was partially offset by the timing of payments to vendors and a decrease of $6.3 million in spending on nuclear refueling outages in 2021.

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Management's Financial Discussion and Analysis

Investing Activities

Net cash flow used in investing activities decreased $27.9 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to:

•a decrease of $33.4 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 service deliveries, and the timing of cash payments during the nuclear fuel cycle;

•a decrease of $14.3 million in nuclear construction expenditures primarily as a result of work performed in 2020 on various ANO 2 outage projects;

•a decrease of $13.4 million in transmission construction expenditures primarily due to a lower scope of work performed in 2021 as compared to 2020; and

•money pool activity.

The decrease was partially offset by $55 million in proceeds received from the DOE in 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.

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 $12.5 million for the three months ended March 31, 2021 compared to increasing by $24.9 million for the three months ended March 31, 2020. 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 decreased $112.2 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to:

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

•issuance of $100 million of 4.00% Series mortgage bonds in March 2020;

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

•net repayments of long-term borrowings of $7.4 million in 2021 compared to net long-term borrowings of $28.7 million in 2020 on the Entergy Arkansas nuclear fuel company variable interest entity credit facility.

The decrease 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 $21.6 million for the three months ended March 31, 2020.

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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Entergy Arkansas, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Capital Structure

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

	March 31, 2021		December 31, 2020
Debt to capital	54.1	%	54.8	%
Effect of subtracting cash	(0.8	%)	(1.2	%)
Net debt to net capital	53.3	%	53.6	%

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 they provide 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.

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

March 31, 2021	December 31, 2020	March 31, 2020	December 31, 2019
(In Thousands)
$15,610	$3,110	$24,935	($21,634)

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 September 2024. Entergy Arkansas also has a $25 million credit facility scheduled to expire in April 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, 2021, no cash borrowings and no letters of credit were 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, 2021, a $1 million letter of credit was outstanding under Entergy Arkansas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional 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 September 2022.  As of March 31, 2021, $4.8 million in loans were outstanding under the credit facility for the Entergy Arkansas 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 facility.

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Entergy Arkansas, LLC and Subsidiaries

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.

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021, the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

Energy Cost Recovery Rider

In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

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Management's Financial Discussion and Analysis

Net Metering Legislation

See the Form 10-K for discussion of Arkansas net metering legislation and subsequent APSC net metering proceedings. In January 2021, Entergy Arkansas, pursuant to an APSC order, filed an updated net metering tariff, which was approved in February 2021.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 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.

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, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING REVENUES
Electric	$583,386	$481,912
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	126,181	87,411
Purchased power	70,221	46,041
Nuclear refueling outage expenses	12,647	16,247
Other operation and maintenance	154,908	151,857
Decommissioning	19,000	17,941
Taxes other than income taxes	29,743	31,060
Depreciation and amortization	88,279	83,521
Other regulatory charges (credits) - net	(37,467)	(20,001)
TOTAL	463,512	414,077
OPERATING INCOME	119,874	67,835
OTHER INCOME
Allowance for equity funds used during construction	2,993	2,917
Interest and investment income	27,887	7,938
Miscellaneous - net	(5,791)	(6,436)
TOTAL	25,089	4,419
INTEREST EXPENSE
Interest expense	33,786	35,623
Allowance for borrowed funds used during construction	(1,290)	(1,281)
TOTAL	32,496	34,342
INCOME BEFORE INCOME TAXES	112,467	37,912
Income taxes	19,430	(6,683)
NET INCOME	$93,037	$44,595
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, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING ACTIVITIES
Net income	$93,037	$44,595
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	126,630	123,160
Deferred income taxes, investment tax credits, and non-current taxes accrued	42,885	8,251
Changes in assets and liabilities:
Receivables	(56,256)	32,820
Fuel inventory	17,930	(9,419)
Accounts payable	(21,622)	(42,694)
Taxes accrued	8,365	9,302
Interest accrued	18,837	16,839
Deferred fuel costs	(55,704)	23,594
Other working capital accounts	(8,025)	(2,691)
Provisions for estimated losses	(12,383)	4,695
Other regulatory assets	42,388	(13,187)
Other regulatory liabilities	(38,604)	(161,989)
Pension and other postretirement liabilities	(25,116)	11,704
Other assets and liabilities	(40,789)	164,694
Net cash flow provided by operating activities	91,573	209,674
INVESTING ACTIVITIES
Construction expenditures	(146,334)	(179,117)
Allowance for equity funds used during construction	2,993	2,917
Nuclear fuel purchases	(17,621)	(52,211)
Proceeds from sale of nuclear fuel	16,059	17,210
Proceeds from nuclear decommissioning trust fund sales	143,575	115,030
Investment in nuclear decommissioning trust funds	(148,783)	(121,003)
Change in money pool receivable - net	(12,500)	(24,935)
Changes in securitization account	—	(3,443)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	—	55,001
Net cash flow used in investing activities	(162,611)	(190,551)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	604,760	264,505
Retirement of long-term debt	(613,706)	(127,203)
Changes in money pool payable - net	—	(21,634)
Other	11,636	(818)
Net cash flow provided by financing activities	2,690	114,850
Net increase (decrease) in cash and cash equivalents	(68,348)	133,973
Cash and cash equivalents at beginning of period	192,128	3,519
Cash and cash equivalents at end of period	$123,780	$137,492
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$14,359	$17,578
See Notes to Financial Statements.

85

ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$122	$24,108
Temporary cash investments	123,658	168,020
Total cash and cash equivalents	123,780	192,128
Accounts receivable:
Customer	215,233	183,719
Allowance for doubtful accounts	(21,176)	(18,334)
Associated companies	56,711	34,216
Other	69,110	35,845
Accrued unbilled revenues	93,324	109,000
Total accounts receivable	413,202	344,446
Deferred fuel costs	2,506	—
Fuel inventory - at average cost	25,881	43,811
Materials and supplies - at average cost	243,721	237,640
Deferred nuclear refueling outage costs	26,613	32,692
Prepayments and other	15,134	13,296
TOTAL	850,837	864,013
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,311,053	1,273,921
Other	340	341
TOTAL	1,311,393	1,274,262
UTILITY PLANT
Electric	12,963,731	12,905,322
Construction work in progress	288,269	234,213
Nuclear fuel	143,835	163,044
TOTAL UTILITY PLANT	13,395,835	13,302,579
Less - accumulated depreciation and amortization	5,323,933	5,255,355
UTILITY PLANT - NET	8,071,902	8,047,224
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	1,789,996	1,832,384
Deferred fuel costs	68,353	68,220
Other	20,675	14,028
TOTAL	1,879,024	1,914,632
TOTAL ASSETS	$12,113,156	$12,100,131
See Notes to Financial Statements.

86

ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$90,000	$485,000
Accounts payable:
Associated companies	39,361	59,448
Other	190,966	208,591
Customer deposits	92,626	98,506
Taxes accrued	90,202	81,837
Interest accrued	41,582	22,745
Deferred fuel costs	—	53,065
Other	40,776	40,628
TOTAL	585,513	1,049,820
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,326,518	1,286,123
Accumulated deferred investment tax credits	30,200	30,500
Regulatory liability for income taxes - net	452,987	467,031
Other regulatory liabilities	662,312	686,872
Decommissioning	1,333,159	1,314,160
Accumulated provisions	57,786	70,169
Pension and other postretirement liabilities	336,515	361,682
Long-term debt	3,868,751	3,482,507
Other	90,209	75,098
TOTAL	8,158,437	7,774,142
Commitments and Contingencies
EQUITY
Member's equity	3,369,206	3,276,169
TOTAL	3,369,206	3,276,169
TOTAL LIABILITIES AND EQUITY	$12,113,156	$12,100,131
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, 2021 and 2020
(Unaudited)
	Member's Equity
	(In Thousands)
Balance at December 31, 2019	$3,125,937
Net income	44,595
Balance at March 31, 2020	$3,170,532
Balance at December 31, 2020	$3,276,169
Net income	93,037
Balance at March 31, 2021	$3,369,206
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Laura, Hurricane Delta, and Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of Entergy Louisiana’s service area. See Note 2 to the financial statements herein for discussion of storm cost recovery filings made by Entergy Louisiana in April 2021.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Louisiana’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Louisiana were approximately $285 million in February 2021 compared to approximately $95 million in February 2020. See Note 2 to the financial statements herein for discussion of the storm cost recovery filing made by Entergy Louisiana in April 2021. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Louisiana.

Results of Operations

Net Income

Net income decreased $22.8 million primarily due to the $58 million reduction in income tax expense resulting from an IRS settlement in the first quarter 2020 related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing, which also resulted in a $29 million ($21 million net-of-tax) regulatory charge to reflect Entergy Louisiana’s agreement to share the savings with customers. Also contributing to the decrease was higher other operation and maintenance expenses, higher interest expense, and a higher effective income tax rate. The decrease was partially offset by higher retail electric price and higher volume/weather. See Note 3 to the financial statements in the Form 10-K for further discussion of the tax settlement.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2021 to the first quarter 2020:

	Amount
	(In Millions)
2020 operating revenues	$930.6
Fuel, rider, and other revenues that do not significantly affect net income	88.1
Retail electric price	52.4
Volume/weather	36.5
2021 operating revenues	$1,107.6

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 interim increase in formula rate plan revenues effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station;

•an increase in formula rate plan revenues and an increase in the transmission recovery mechanism effective September 2020; and

•an interim increase in formula rate plan revenues effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center.

See Note 2 to the financial statements herein and 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 more favorable weather on residential sales and an increase in usage during the unbilled sales period. The increase is partially offset by a decrease in industrial usage and decreased demand from mid to small customers. The decrease in industrial usage is primarily due to decreased demand from existing customers in the chemicals and petroleum refining industries as a result of the COVID-19 pandemic and plant shutdowns and operational issues. The decrease in industrial usage is partially offset by an increase in demand from expansion projects, primarily in the transportation and chemicals industries. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Billed electric energy sales for Entergy Louisiana for the three months ended March 31, 2021 and 2020 are as follows:

	2021	2020	% Change
	(GWh)
Residential	3,500	2,975	18
Commercial	2,409	2,459	(2)
Industrial	7,010	7,450	(6)
Governmental	197	199	(1)
Total retail	13,116	13,083	—
Sales for resale:
Associated companies	959	1,341	(28)
Non-associated companies	386	457	(16)
Total	14,461	14,881	(3)

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 $8.9 million in nuclear generation expenses primarily due to spending on sanitation and social distancing protocols, as a result of the COVID-19 pandemic;

•a decrease of $4.2 million in nuclear insurance refunds; and

•an increase of $1.5 million in non-nuclear generation expenses due to higher expenses associated with the Lake Charles Power Station, which began commercial operation in March 2020, partially offset by a lower scope of work performed during plant outages in 2021 as compared to the prior year.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station, which was placed in service in March 2020.

Other regulatory charges (credits) - net include regulatory charges of $29 million recorded in first quarter 2020 due to a settlement with the IRS related to the uncertain tax position regarding Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers. See Note 3 in the Form 10-K for further discussion of the settlement and savings obligation.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project. The decrease was substantially offset by changes in decommissioning trust fund activity.

Interest expense increased primarily due to:

•the issuance of $350 million of 2.90% Series mortgage bonds in March 2020;

•the issuance of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;

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

•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project.

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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 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020.

Income Taxes

The effective income tax rate was 18.5% 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 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.

The effective income tax rate was (36.0%) for the first quarter 2020. The difference in the effective income tax rate for the first quarter 2020 versus the federal statutory rate of 21% was primarily due to the settlement with the IRS on the treatment of funds received in conjunction with the Louisiana Act 55 financing of Hurricane Isaac storm costs, permanent differences related to income tax deductions for stock-based compensation, 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, book and tax differences related to the allowance for equity funds used during construction, and the amortization of excess accumulated deferred income taxes, partially offset by state income taxes. See Note 3 in the Form 10-K for discussion of the IRS settlement and the income tax deductions for stock-based compensation. 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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Cash and cash equivalents at beginning of period	$728,020	$2,006
Cash flow provided by (used in):
Operating activities	(54,598)	313,799
Investing activities	(1,098,466)	(373,239)
Financing activities	1,026,860	522,828
Net increase (decrease) in cash and cash equivalents	(126,204)	463,388
Cash and cash equivalents at end of period	$601,816	$465,394

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Operating Activities

Entergy Louisiana’s operating activities used $54.6 million of cash for the three months ended March 31, 2021 compared to providing $313.8 million of cash for the three months ended March 31, 2020 primarily due to:

•an increase of approximately $170 million in storm spending in 2021, primarily due to Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•an increase of $24 million in spending on nuclear refueling outages;

•income tax refunds of $20.7 million in 2020. Entergy Louisiana had income tax refunds in 2020 as a result of a refund of an overpayment on a prior year state income tax return; and

•an increase of $20.5 million in pension contributions 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.

Investing Activities

Net cash flow used in investing activities increased $725.2 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to:

•an increase of 437.9 million in distribution construction expenditures primarily due to storm spending in 2021. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•an increase of $162.6 million in transmission construction expenditures primarily due to storm spending in 2021. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•an increase of $68.3 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;

•$39.5 million in net receipts from storm reserve escrow accounts in the first quarter 2020; and

•an increase of $19.7 million in nuclear construction expenditures primarily due to increased spending on various projects in 2021.

The increase was partially offset by:

•a decrease of $19.7 million in non-nuclear generation construction expenditures due to a lower scope of work performed in 2021 as compared to 2020; and

•money pool activity.

Increases in Entergy Louisiana’s receivable from the money pool are a use of cash flow, and Entergy Louisiana’s receivable from the money pool increased by $62.3 million for the three months ended March 31, 2021 compared to increasing by $84.5 million for the three months ended March 31, 2020. 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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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Financing Activities

Net cash flow provided by financing activities increased $504 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 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, as compared to the issuances of $350 million of 2.90% Series mortgage bonds and $300 million of 4.20% Series mortgage bonds, each in March 2020;

•net long-term borrowings of $85.5 million in 2021 compared to net repayments of long-term borrowings of $28.5 million in 2020 on the nuclear fuel company variable interest entities’ credit facilities;

•money pool activity; and

•the payment of $11.5 million in common equity distributions in March 2020 primarily to maintain Entergy Louisiana’s capital structure.

The decrease was partially offset by the repayment of Entergy Louisiana Waterford VIE’s $40 million of 3.92% Series H secured notes in February 2021.

Decreases in Entergy Louisiana’s payable to the money pool are a use of cash flow, and Entergy Louisiana’s payable to the money pool decreased by $82.8 million for the three months ended March 31, 2020.

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 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 issuance of $1 billion of mortgage bonds in March 2021.

	March 31, 2021		December 31, 2020
Debt to capital	56.9	%	54.8	%
Effect of excluding securitization bonds	0.0	%	0.0	%
Debt to capital, excluding securitization bonds (a)	56.9	%	54.8	%
Effect of subtracting cash	(1.5	%)	(2.1	%)
Net debt to net capital, excluding securitization bonds (a)	55.4	%	52.7	%

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

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 ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because the securitization bonds are non-recourse to Entergy Louisiana, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy Louisiana 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 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.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

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, 2021	December 31, 2020	March 31, 2020	December 31, 2019
(In Thousands)
$75,772	$13,426	$84,466	($82,826)

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 September 2024.  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, 2021, 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, 2021, $12.8 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 September 2022.  As of March 31, 2021, $70.5 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, 2021, $73.2 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.

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.

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Fuel and purchased power recovery

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded 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.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

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, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING REVENUES
Electric	$1,079,663	$912,541
Natural gas	27,981	18,106
TOTAL	1,107,644	930,647
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	145,234	144,492
Purchased power	209,961	160,743
Nuclear refueling outage expenses	13,282	13,630
Other operation and maintenance	237,483	222,658
Decommissioning	16,823	16,001
Taxes other than income taxes	52,484	50,077
Depreciation and amortization	160,813	145,135
Other regulatory charges (credits) - net	31,097	11,132
TOTAL	867,177	763,868
OPERATING INCOME	240,467	166,779
OTHER INCOME
Allowance for equity funds used during construction	6,101	14,887
Interest and investment income	72,515	(19,669)
Miscellaneous - net	(34,638)	49,601
TOTAL	43,978	44,819
INTEREST EXPENSE
Interest expense	82,806	79,517
Allowance for borrowed funds used during construction	(2,759)	(7,132)
TOTAL	80,047	72,385
INCOME BEFORE INCOME TAXES	204,398	139,213
Income taxes	37,772	(50,183)
NET INCOME	$166,626	$189,396
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, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
Net Income	$166,626	$189,396
Other comprehensive income (loss)
Pension and other postretirement liabilities (net of tax expense (benefit) of ($144) and $3,340)	(407)	9,467
Other comprehensive income (loss)	(407)	9,467
Comprehensive Income	$166,219	$198,863
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, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING ACTIVITIES
Net income	$166,626	$189,396
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	198,868	191,447
Deferred income taxes, investment tax credits, and non-current taxes accrued	67,823	(39,681)
Changes in working capital:
Receivables	(13,080)	23,004
Fuel inventory	1,194	(456)
Accounts payable	(126,070)	(86,317)
Prepaid taxes and taxes accrued	20,619	48,840
Interest accrued	(9,163)	(2,384)
Deferred fuel costs	(203,815)	(18,280)
Other working capital accounts	(25,628)	(3,156)
Changes in provisions for estimated losses	(258)	(41,113)
Changes in other regulatory assets	(70,784)	55,539
Changes in other regulatory liabilities	22,503	(129,370)
Changes in pension and other postretirement liabilities	(30,745)	(22,806)
Other	(52,688)	149,136
Net cash flow provided by (used in) operating activities	(54,598)	313,799
INVESTING ACTIVITIES
Construction expenditures	(945,831)	(344,522)
Allowance for equity funds used during construction	6,101	14,887
Nuclear fuel purchases	(52,435)	(18,052)
Proceeds from the sale of nuclear fuel	—	33,889
Receipts from storm reserve escrow account	—	40,589
Payments to storm reserve escrow account	—	(1,113)
Changes to securitization account	(6,050)	(5,348)
Proceeds from nuclear decommissioning trust fund sales	291,275	144,962
Investment in nuclear decommissioning trust funds	(329,180)	(154,065)
Changes in money pool receivable - net	(62,346)	(84,466)
Net cash flow used in investing activities	(1,098,466)	(373,239)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,399,245	1,221,900
Retirement of long-term debt	(368,707)	(603,607)
Change in money pool payable - net	—	(82,826)
Common equity distributions paid	—	(11,500)
Other	(3,678)	(1,139)
Net cash flow provided by financing activities	1,026,860	522,828
Net increase (decrease) in cash and cash equivalents	(126,204)	463,388
Cash and cash equivalents at beginning of period	728,020	2,006
Cash and cash equivalents at end of period	$601,816	$465,394
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$89,432	$79,794
Income taxes	$—	($20,684)
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$233	$1,303
Temporary cash investments	601,583	726,717
Total cash and cash equivalents	601,816	728,020
Accounts receivable:
Customer	326,475	317,905
Allowance for doubtful accounts	(46,655)	(45,693)
Associated companies	144,640	81,624
Other	39,401	41,760
Accrued unbilled revenues	186,001	178,840
Total accounts receivable	649,862	574,436
Deferred fuel costs	206,065	2,250
Fuel inventory	49,486	50,680
Materials and supplies - at average cost	433,841	437,933
Deferred nuclear refueling outage costs	75,916	48,407
Prepayments and other	41,100	36,813
TOTAL	2,058,086	1,878,539
OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests	1,390,587	1,390,587
Decommissioning trust funds	1,879,332	1,794,042
Non-utility property - at cost (less accumulated depreciation)	335,730	323,110
Other	13,521	13,399
TOTAL	3,619,170	3,521,138
UTILITY PLANT
Electric	25,960,969	25,619,789
Natural gas	268,865	262,744
Construction work in progress	526,575	667,281
Nuclear fuel	252,555	210,128
TOTAL UTILITY PLANT	27,008,964	26,759,942
Less - accumulated depreciation and amortization	9,502,347	9,372,224
UTILITY PLANT - NET	17,506,617	17,387,718
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $— as of March 31, 2021 and $5,088 as of December 31, 2020)	1,796,850	1,726,066
Deferred fuel costs	168,122	168,122
Other	32,212	23,924
TOTAL	1,997,184	1,918,112
TOTAL ASSETS	$25,181,057	$24,705,507
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$200,000	$240,000
Accounts payable:
Associated companies	75,431	103,148
Other	685,493	1,450,008
Customer deposits	151,307	152,612
Taxes accrued	63,236	42,617
Interest accrued	83,086	92,249
Current portion of unprotected excess accumulated deferred income taxes	31,138	31,138
Other	60,652	62,968
TOTAL	1,350,343	2,174,740
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,193,429	2,138,522
Accumulated deferred investment tax credits	106,135	107,317
Regulatory liability for income taxes - net	436,577	447,628
Other regulatory liabilities	951,847	918,293
Decommissioning	1,592,903	1,573,307
Accumulated provisions	24,681	24,939
Pension and other postretirement liabilities	661,999	692,728
Long-term debt (includes securitization bonds of $10,344 as of March 31, 2021 and $10,278 as of December 31, 2020)	9,859,885	8,787,451
Other	379,367	382,894
TOTAL	16,206,823	15,073,079
Commitments and Contingencies
EQUITY
Member's equity	7,619,971	7,453,361
Accumulated other comprehensive income	3,920	4,327
TOTAL	7,623,891	7,457,688
TOTAL LIABILITIES AND EQUITY	$25,181,057	$24,705,507
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, 2021 and 2020
(Unaudited)
	Common Equity
	Member’s Equity	Accumulated Other Comprehensive Income	Total
	(In Thousands)
Balance at December 31, 2019	$6,392,556	$4,562	$6,397,118
Net income	189,396	—	189,396
Other comprehensive income	—	9,467	9,467
Distributions declared on common equity	(11,500)	—	(11,500)
Other	(10)	—	(10)
Balance at March 31, 2020	$6,570,442	$14,029	$6,584,471
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
See Notes to Financial Statements.

104

ENTERGY MISSISSIPPI, LLC

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in Entergy Mississippi’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Mississippi were approximately $65 million in February 2021 compared to approximately $35 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of storm cost recovery and fuel cost recovery at Entergy Mississippi.

In February 2021 the MPSC announced that it would launch a comprehensive review of the condition and resiliency of the state’s public utility infrastructure in response to the impacts of the February 2021 winter storms. Although the MPSC did not open a formal docket, the MPSC submitted data requests to Entergy Mississippi regarding the actions taken to ensure reliable operations of the electric network during the winter storm events and in anticipation of other future extreme weather events. In April 2021 the MPSC opened a docket to investigate Entergy Mississippi’s membership in MISO. In the order, the MPSC noted the impact of the February 2021 winter storms, stating that it observed “excessive prices of natural gas and electricity” during the winter event. The MPSC has requested comments due 75 days after publication of the order.

Results of Operations

Net Income

Net income increased $3.4 million primarily due to higher retail electric price and higher volume/weather, partially offset by higher other operation and maintenance expenses, a higher effective income tax rate, and higher depreciation and amortization expenses.

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2021 to the first quarter 2020:

	Amount
	(In Millions)
2020 operating revenues	$293.9
Fuel, rider, and other revenues that do not significantly affect net income	22.9
Retail electric price	12.3
Volume/weather	7.5
2021 operating revenues	$336.6

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

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Management's Financial Discussion and Analysis

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 with the first billing cycle of April 2020 and the implementation of a vegetation management rider effective with the April 2020 billing cycle. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filings and the vegetation management rider.

The volume/weather variance is primarily due to an increase of 213 GWh, or 7%, in billed electricity usage, including the effect of more favorable weather on residential sales, partially offset by a decrease in industrial usage.

Billed electric energy sales for Entergy Mississippi for the three months ended March 31, 2021 and 2020 are as follows:

	2021	2020	% Change
	(GWh)
Residential	1,495	1,250	20
Commercial	1,009	1,006	—
Industrial	520	556	(6)
Governmental	95	94	1
Total retail	3,119	2,906	7
Sales for resale:
Non-associated companies	1,452	827	76
Total	4,571	3,733	22

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

Other Income Statement Variances

Other operation and maintenance expenses increased primarily due to:

•an increase of $4.1 million in vegetation maintenance costs;

•an increase of $1.4 million due to bad debt expense as a result of the COVID-19 pandemic; and

•an increase of $1.4 million as a result of the amount of transmission costs allocated by MISO. See Note 2 to the financial statements for further information on the recovery of these costs.

The increase was partially offset by a decrease of $1.1 million in energy efficiency costs.

Depreciation and amortization expenses increased primarily as a result of additions to plant in service.

Income Taxes

The effective income tax rate was 22.2% 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 certain book and tax differences related to utility plant items, partially offset by state income taxes.

The effective income tax rate was 7.7% for the first quarter 2020. The difference in the effective income tax rate for the first quarter 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items and permanent differences related to income tax deductions for stock-based

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compensation, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for a discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Cash and cash equivalents at beginning of period	$18	$51,601
Cash flow provided by (used in):
Operating activities	54,311	33,261
Investing activities	(162,802)	(103,615)
Financing activities	185,189	18,772
Net increase (decrease) in cash and cash equivalents	76,698	(51,582)
Cash and cash equivalents at end of period	$76,716	$19

Operating Activities

Net cash flow provided by operating activities increased $21.1 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to the timing of payments to vendors. The increase was partially offset by increased fuel costs as a result of Winter Storm Uri and the timing of collections of receivables from customers, in part due to the COVID-19 pandemic. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements in the Form 10-K for a discussion of fuel and purchased power cost recovery.

Investing Activities

Net cash flow used in investing activities increased $59.2 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to money pool activity and an increase of $43.5 million in distribution construction expenditures primarily due to increased spending on the reliability and infrastructure of Entergy Mississippi’s distribution system in 2021 as compared to 2020. The increase was partially offset by $24.6 million in plant upgrades for Choctaw Generating Station in March 2020.

Increases in Entergy Mississippi’s receivable from the money pool are a use of cash flow, and Entergy Mississippi’s receivable from the money pool increased by $9.7 million for the three months ended March 31, 2021 compared to decreasing $44.7 million for the three months ended March 31, 2020. 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 increased $166.4 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to the issuance of $200 million of 3.5% Series mortgage bonds in March 2021, partially offset by money pool activity. 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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Decreases in Entergy Mississippi’s payable to the money pool are a use of cash flow, and Entergy Mississippi’s payable to the money pool decreased by $16.5 million for the three months ended March 31, 2021 compared to increasing by $19 million for the three months ended March 31, 2020.

Capital Structure

Entergy Mississippi’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy Mississippi is primarily due to the issuance of $200 million of mortgage bonds in March 2021.

	March 31, 2021		December 31, 2020
Debt to capital	54.0	%	51.7	%
Effect of subtracting cash	(1.0	%)	—	%
Net debt to net capital	53.0	%	51.7	%

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 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, 2021	December 31, 2020	March 31, 2020	December 31, 2019
(In Thousands)
$9,683	($16,516)	($19,006)	$44,693

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

Entergy Mississippi has 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, 2021.  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, 2021, $1 million of MISO letters of credit and $1 million of 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.

Entergy Mississippi has $33 million in its storm reserve escrow account at March 31, 2021.

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Entergy Mississippi, LLC

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 the formula rate plan and fuel and purchased power cost recovery. The following are updates to that discussion.

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 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.

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Management's Financial Discussion and Analysis

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.

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ENTERGY MISSISSIPPI, LLC
INCOME STATEMENTS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING REVENUES
Electric	$336,619	$293,922
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	60,197	63,297
Purchased power	68,591	52,643
Other operation and maintenance	67,831	62,337
Taxes other than income taxes	25,899	27,190
Depreciation and amortization	55,036	51,155
Other regulatory charges (credits) - net	8,129	(3,881)
TOTAL	285,683	252,741
OPERATING INCOME	50,936	41,181
OTHER DEDUCTIONS
Allowance for equity funds used during construction	1,668	1,439
Interest and investment income	42	120
Miscellaneous - net	(2,313)	(2,296)
TOTAL	(603)	(737)
INTEREST EXPENSE
Interest expense	17,613	16,583
Allowance for borrowed funds used during construction	(677)	(551)
TOTAL	16,936	16,032
INCOME BEFORE INCOME TAXES	33,397	24,412
Income taxes	7,425	1,886
NET INCOME	$25,972	$22,526
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING ACTIVITIES
Net income	$25,972	$22,526
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization	55,036	51,155
Deferred income taxes, investment tax credits, and non-current taxes accrued	22,593	2,762
Changes in assets and liabilities:
Receivables	4,557	17,971
Fuel inventory	1,736	(3,266)
Accounts payable	26,391	(8,125)
Taxes accrued	(75,886)	(58,651)
Interest accrued	4,238	6,201
Deferred fuel costs	(25,722)	13,406
Other working capital accounts	(3,425)	7,849
Provisions for estimated losses	(7,689)	(47)
Other regulatory assets	11,015	(8,484)
Other regulatory liabilities	19,147	(5,532)
Pension and other postretirement liabilities	(5,668)	(2,482)
Other assets and liabilities	2,016	(2,022)
Net cash flow provided by operating activities	54,311	33,261
INVESTING ACTIVITIES
Construction expenditures	(154,788)	(124,986)
Allowance for equity funds used during construction	1,668	1,439
Changes in money pool receivable - net	(9,683)	44,693
Payment for the purchase of plant or assets	—	(24,633)
Other	1	(128)
Net cash flow used in investing activities	(162,802)	(103,615)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	200,573	—
Changes in money pool payable - net	(16,516)	19,006
Common equity distributions paid	—	(2,500)
Other	1,132	2,266
Net cash flow provided by financing activities	185,189	18,772
Net increase (decrease) in cash and cash equivalents	76,698	(51,582)
Cash and cash equivalents at beginning of period	18	51,601
Cash and cash equivalents at end of period	$76,716	$19
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$12,757	$9,800
Income taxes	($8,045)	$—
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
ASSETS
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$11	$11
Temporary cash investments	76,705	7
Total cash and cash equivalents	76,716	18
Accounts receivable:
Customer	104,649	105,732
Allowance for doubtful accounts	(16,771)	(19,527)
Associated companies	13,857	2,740
Other	13,596	11,821
Accrued unbilled revenues	50,075	59,514
Total accounts receivable	165,406	160,280
Deferred fuel costs	11,031	—
Fuel inventory - at average cost	15,381	17,117
Materials and supplies - at average cost	61,336	59,542
Prepayments and other	3,792	4,876
TOTAL	333,662	241,833
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,539	4,543
Escrow accounts	64,637	64,635
TOTAL	69,176	69,178
UTILITY PLANT
Electric	6,151,971	6,084,730
Construction work in progress	192,649	134,854
TOTAL UTILITY PLANT	6,344,620	6,219,584
Less - accumulated depreciation and amortization	2,046,216	2,005,087
UTILITY PLANT - NET	4,298,404	4,214,497
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	456,326	467,341
Other	19,886	14,413
TOTAL	476,212	481,754
TOTAL ASSETS	$5,177,454	$5,007,262
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies	$37,053	$61,727
Other	144,652	117,629
Customer deposits	85,953	86,200
Taxes accrued	32,198	108,084
Interest accrued	25,127	20,889
Deferred fuel costs	—	14,691
Other	32,239	34,270
TOTAL	357,222	443,490
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	664,704	646,674
Accumulated deferred investment tax credits	11,080	9,062
Regulatory liability for income taxes - net	222,078	224,000
Other regulatory liabilities	36,897	15,828
Asset retirement cost liabilities	9,898	9,762
Accumulated provisions	38,815	46,504
Pension and other postretirement liabilities	105,176	110,901
Long-term debt	1,981,429	1,780,577
Other	51,449	47,730
TOTAL	3,121,526	2,891,038
Commitments and Contingencies
EQUITY
Member's equity	1,698,706	1,672,734
TOTAL	1,698,706	1,672,734
TOTAL LIABILITIES AND EQUITY	$5,177,454	$5,007,262
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	Member's Equity
	(In Thousands)
Balance at December 31, 2019	$1,542,151
Net income	22,526
Common equity distributions	(2,500)
Balance at March 31, 2020	$1,562,177
Balance at December 31, 2020	$1,672,734
Net income	25,972
Balance at March 31, 2021	$1,698,706
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Zeta, which caused significant damage to Entergy New Orleans’s service area. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy New Orleans’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy New Orleans were approximately $35 million in February 2021 compared to approximately $25 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of fuel cost recovery at Entergy New Orleans. See “Load Shed Investigation” below for discussion of the investigation initiated by the City Council in February 2021 .

Results of Operations

Net Income

Net income decreased $9.4 million primarily due to higher other operation and maintenance expenses, partially offset by higher retail electric price.

Operating Revenues

Following is an analysis of the change in operating revenues comparing first quarter 2021 to first quarter 2020:

	Amount
	(In Millions)
2020 operating revenues	$149.3
Fuel, rider, and other revenues that do not significantly affect net income	5.3
Retail electric price	15.2
Volume/weather	(0.5)
2021 operating revenues	$169.3

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.

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Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

The retail electric price variance is primarily due to an increase in formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the rate case resolution.

The volume/weather variance is primarily due to decreased commercial and residential usage and the effect of decreased usage during the unbilled sales period, significantly offset by more favorable weather on residential sales.

Billed electric energy sales for Entergy New Orleans for the three months ended March 31, 2021 and 2020 are as follows:

	2021	2020	% Change
	(GWh)
Residential	595	501	19
Commercial	450	496	(9)
Industrial	92	102	(10)
Governmental	171	184	(7)
Total retail	1,308	1,283	2
Sales for resale:
Non-associated companies	89	601	(85)
Total	1,397	1,884	(26)

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 increased primarily due to an increase of $3.6 million in energy efficiency costs and an increase of $3.5 million in non-nuclear generation expenses primarily due to the timing of the scope of work performed during plant outages as compared to the same period in 2020 and the New Orleans Power Station, which was placed in service in May 2020.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the New Orleans Power Station, which was placed in service in May 2020.

Other regulatory charges (credits) - net include regulatory credits recorded in first quarter 2020 to reflect compliance with terms of the 2018 combined rate case resolution approved by the City Council in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of the rate case resolution.

Income Taxes

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.

The effective income tax rate was (32.4%) for first quarter 2020. The difference in the effective income tax rate for first quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, permanent differences related to income tax deductions for stock-based compensation, certain book and tax differences related to utility plant items, and book and tax differences related to

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Management's Financial Discussion and Analysis

the allowance for equity funds used during construction, partially offset by the provision for uncertain tax positions. 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. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Cash and cash equivalents at beginning of period	$26	$6,017
Cash flow provided by (used in):
Operating activities	(14,114)	17,318
Investing activities	14,875	(68,691)
Financing activities	14,825	118,671
Net increase in cash and cash equivalents	15,586	67,298
Cash and cash equivalents at end of period	$15,612	$73,315

Operating Activities

Entergy New Orleans’s operating activities used $14.1 million of cash for the three months ended March 31, 2021 compared to providing $17.3 million of cash for the three months ended March 31, 2020 primarily due to the following activity:

•the timing of payments to vendors;

•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. 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 collection of receivables from customers, in part due to the COVID-19 pandemic; and

•an increase of approximately $5 million in storm spending in 2021, primarily due to Hurricane Zeta restoration efforts. See “Hurricane Zeta” above for discussion of hurricane restoration efforts.

Investing Activities

Entergy New Orleans’s investing activities provided $14.9 million of cash for the three months ended March 31, 2021 compared to using $68.7 million of cash for the three months ended March 31, 2020 primarily due to the following activity:

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

•a decrease of $33.8 million in construction expenditures primarily due to lower spending in 2021 on the New Orleans Power Station and the New Orleans Solar Station projects and lower spending in 2021 on advanced metering infrastructure, partially offset by storm spending in 2021. See “Hurricane Zeta” above for discussion of hurricane restoration efforts.

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Management's Financial Discussion and Analysis

Financing Activities

Net cash flow provided by financing activities decreased $103.8 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to the issuance of $78 million of 3.00% Series mortgage bonds and the issuance of $62 million of 3.75% Series mortgage bonds, each in March 2020. The decrease was partially offset by $20 million in repayments on long-term credit borrowings in 2020 and 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. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

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

	March 31, 2021		December 31, 2020
Debt to capital	51.5	%	51.5	%
Effect of excluding securitization bonds	(1.7	%)	(1.6	%)
Debt to capital, excluding securitization bonds (a)	49.8	%	49.9	%
Effect of subtracting cash	(0.6	%)	—	%
Net debt to net capital, excluding securitization bonds (a)	49.2	%	49.9	%

(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.  

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Management's Financial Discussion and Analysis

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

March 31, 2021	December 31, 2020	March 31, 2020	December 31, 2019
(In Thousands)
($25,229)	($10,190)	$13,170	$5,191

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

Entergy New Orleans has a credit facility in the amount of $25 million scheduled to expire in November 2021. 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, 2021, there were no cash borrowings and no letters of credit 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, 2021, a $2 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.

Entergy New Orleans has $38.8 million in its storm reserve escrow account at March 31, 2021.

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

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 million for costs associated with the COVID-19 pandemic.

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March

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Management's Financial Discussion and Analysis

2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Load Shed Investigation

On February 16, 2021, due to high customer demand and limited generation, MISO issued an order requiring load-serving entities throughout its southern region to shed load to protect the integrity of the bulk electric system. Entergy New Orleans was required to shed load of at least 26 MW, but due to certain complications with its automated load shed program and certain load measurement issues, it inadvertently shed approximately 105 MW of load in its service area. The maximum time any customer was without power due to the load shed event was one hour and forty minutes. In late February 2021 the City Council ordered its advisors to conduct an investigation into the load shed event and to issue a report, which was completed and filed in April 2021. The report recommended that the City Council open an additional docket to determine whether any of Entergy New Orleans’s actions were imprudent, and the City Council Utility Committee Chairperson has made statements in the media that the City Council may seek to impose a fine on Entergy New Orleans. Entergy New Orleans would oppose any attempt to levy a fine under the circumstances presented.

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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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING REVENUES
Electric	$139,148	$123,431
Natural gas	30,187	25,871
TOTAL	169,335	149,302
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	19,012	27,495
Purchased power	68,670	56,467
Other operation and maintenance	38,178	30,704
Taxes other than income taxes	12,556	13,206
Depreciation and amortization	18,161	15,075
Other regulatory charges (credits) - net	3,130	(5,736)
TOTAL	159,707	137,211
OPERATING INCOME	9,628	12,091
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	258	2,485
Interest and investment income	9	53
Miscellaneous - net	(302)	(738)
TOTAL	(35)	1,800
INTEREST EXPENSE
Interest expense	7,029	6,640
Allowance for borrowed funds used during construction	(116)	(1,195)
TOTAL	6,913	5,445
INCOME BEFORE INCOME TAXES	2,680	8,446
Income taxes	909	(2,740)
NET INCOME	$1,771	$11,186
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, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING ACTIVITIES
Net income	$1,771	$11,186
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation and amortization	18,161	15,075
Deferred income taxes, investment tax credits, and non-current taxes accrued	4,572	1,339
Changes in assets and liabilities:
Receivables	(1,975)	4,039
Fuel inventory	2,234	(25)
Accounts payable	(27,777)	(5,291)
Taxes accrued	13	122
Interest accrued	(3,203)	(929)
Deferred fuel costs	(4,886)	3,702
Other working capital accounts	(11,103)	(10,795)
Provisions for estimated losses	(40,680)	923
Other regulatory assets	28,879	1,867
Other regulatory liabilities	8,728	(9,599)
Pension and other postretirement liabilities	(4,397)	(4,878)
Other assets and liabilities	15,549	10,582
Net cash flow provided by (used in) operating activities	(14,114)	17,318
INVESTING ACTIVITIES
Construction expenditures	(26,165)	(60,001)
Allowance for equity funds used during construction	258	2,485
Changes in money pool receivable - net	—	(7,979)
Receipts from storm reserve escrow account	44,200	—
Payments to storm reserve escrow account	(3)	(314)
Changes in securitization account	(3,415)	(2,882)
Net cash flow provided by (used in) investing activities	14,875	(68,691)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—	139,116
Retirement of long-term debt	—	(20,000)
Change in money pool payable - net	15,039	—
Other	(214)	(445)
Net cash flow provided by financing activities	14,825	118,671
Net increase in cash and cash equivalents	15,586	67,298
Cash and cash equivalents at beginning of period	26	6,017
Cash and cash equivalents at end of period	$15,612	$73,315
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$9,921	$7,275
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$15,612	$26
Total cash and cash equivalents	15,612	26
Securitization recovery trust account	6,779	3,364
Accounts receivable:
Customer	82,902	70,694
Allowance for doubtful accounts	(19,365)	(17,430)
Associated companies	1,331	2,381
Other	5,060	4,248
Accrued unbilled revenues	23,009	31,069
Total accounts receivable	92,937	90,962
Deferred fuel costs	7,016	2,130
Fuel inventory - at average cost	—	1,978
Materials and supplies - at average cost	16,434	16,550
Prepayments and other	14,733	3,715
TOTAL	153,511	118,725
OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)	1,016	1,016
Storm reserve escrow account	38,841	83,038
TOTAL	39,857	84,054
UTILITY PLANT
Electric	1,806,961	1,821,638
Natural gas	352,817	348,024
Construction work in progress	26,927	12,460
TOTAL UTILITY PLANT	2,186,705	2,182,122
Less - accumulated depreciation and amortization	751,117	740,796
UTILITY PLANT - NET	1,435,588	1,441,326
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs	4,080	4,080
Other regulatory assets (includes securitization property of $32,859 as of March 31, 2021 and $35,559 as of December 31, 2020)	237,911	266,790
Other	29,864	23,931
TOTAL	271,855	294,801
TOTAL ASSETS	$1,900,811	$1,938,906
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT LIABILITIES
Payable due to associated company	$1,618	$1,618
Accounts payable:
Associated companies	66,122	54,234
Other	40,944	60,766
Customer deposits	27,315	27,912
Taxes accrued	4,713	4,700
Interest accrued	4,892	8,095
Current portion of unprotected excess accumulated deferred income taxes	3,327	3,296
Other	6,160	5,462
TOTAL	155,091	166,083
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	341,217	338,714
Accumulated deferred investment tax credits	16,081	16,095
Regulatory liability for income taxes - net	55,180	55,675
Asset retirement cost liabilities	3,833	3,768
Accumulated provisions	49,218	89,898
Long-term debt (includes securitization bonds of $41,352 as of March 31, 2021 and $41,291 as of December 31, 2020)	629,883	629,704
Long-term payable due to associated company	10,911	10,911
Other	30,709	21,141
TOTAL	1,137,032	1,165,906
Commitments and Contingencies
EQUITY
Member's equity	608,688	606,917
TOTAL	608,688	606,917
TOTAL LIABILITIES AND EQUITY	$1,900,811	$1,938,906
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	Member's Equity
	(In Thousands)
Balance at December 31, 2019	$497,579
Net income	11,186
Balance at March 31, 2020	$508,765
Balance at December 31, 2020	$606,917
Net income	1,771
Balance at March 31, 2021	$608,688
See Notes to Financial Statements.

128

ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Laura and Hurricane Delta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura and Hurricane Delta” in the Form 10-K for a discussion of Hurricane Laura and Hurricane Delta, which caused significant damage to portions of Entergy Texas’s service territory. See Note 2 to the financial statements herein for discussion of storm cost recovery filings made by Entergy Texas in April 2021.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Texas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Texas were approximately $185 million in February 2021 compared to approximately $50 million in February 2020. See Note 2 to the financial statements herein for discussion of the storm cost recovery filing made by Entergy Texas in April 2021. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Texas.

Results of Operations

Net Income

Net income increased $17.4 million primarily due to higher retail electric price and higher volume/weather. The increase was partially offset by a higher effective tax rate, lower other income, and higher depreciation and amortization expenses.

Operating Revenues

Following is an analysis of the change in operating revenues comparing the first quarter 2021 to the first quarter 2020:

	Amount
	(In Millions)
2020 operating revenues	$339.3
Fuel, rider, and other revenues that do not significantly affect net income	105.9
Retail electric price	19.1
Volume/weather	17.3
Return of unprotected excess accumulated deferred income taxes to customers	(1.4)
2021 operating revenues	$480.2

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Management's Financial Discussion and Analysis

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 retail electric price variance is primarily due to the implementation of the generation cost recovery rider effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021. 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.     

The volume/weather variance is primarily due to the effect of more favorable weather on residential sales.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a rider effective October 2018. In first quarter 2021, $7.1 million was returned to customers as compared to $5.7 million in first quarter 2020. There is no effect on net income as the reduction in operating revenues is 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.

Billed electric energy sales for Entergy Texas for the three months ended March 31, 2021 and 2020 are as follows:

	2021	2020	% Change
	(GWh)
Residential	1,539	1,326	16
Commercial	1,000	1,000	—
Industrial	1,928	1,897	2
Governmental	62	64	(3)
Total retail	4,529	4,287	6
Sales for resale:
Associated companies	296	244	21
Non-associated companies	341	85	301
Total	5,166	4,616	12

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 $1.3 million due to bad debt expense as a result of the COVID-19 pandemic;

•an increase of $1.3 million in non-nuclear generation expenses primarily due to higher expenses associated with the Montgomery County Power Station, which was placed in service in January 2021, and a higher scope of work performed in 2021 as compared to the same period in 2020; and

•several individually insignificant items.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes as a result of higher estimated ad valorem taxes associated with the Montgomery County Power Station.

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Management's Financial Discussion and Analysis

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station, which was placed in service in January 2021.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

Interest expense increased primarily due to a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

Income Taxes

The effective income tax rate was 9.1% 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. 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.    

The effective income tax rate was (14.8%) for the first quarter 2020. The difference in the effective income tax rate for the first quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, permanent differences related to income tax deductions for stock-based compensation, book and tax differences related to the allowance for equity funds used during construction, 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. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Cash and cash equivalents at beginning of period	$248,596	$12,929
Cash flow provided by (used in):
Operating activities	(28,864)	37,114
Investing activities	(223,696)	(232,650)
Financing activities	3,989	342,320
Net increase (decrease) in cash and cash equivalents	(248,571)	146,784
Cash and cash equivalents at end of period	$25	$159,713

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Management's Financial Discussion and Analysis

Operating Activities

Entergy Texas’s operating activities used $28.9 million of cash for the three months ended March 31, 2021 compared to providing $37.1 million of cash for the three months ended March 31, 2020 primarily due to increased fuel costs as a result of Winter Storm Uri and an increase of approximately $25 million in storm spending in 2021, primarily due to Hurricane Laura and Hurricane Delta restoration efforts. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts.

Investing Activities

Net cash flow used in investing activities decreased $9.0 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to a decrease of $42.9 million in non-nuclear generation construction expenditures, primarily due to higher spending in 2020 on the Montgomery County Power Station project, and money pool activity. The decrease was partially offset by an increase of $50.7 million in distribution construction expenditures primarily due to storm spending in 2021. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts.

Decreases in Entergy Texas’s receivable from the money pool are a source of cash flow, and Entergy Texas’s receivable from the money pool decreased $4.6 million for the three months ended March 31, 2021 compared to increasing $17.9 million for the three months ended March 31, 2020. 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 decreased $338.3 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to a capital contribution of $175 million received from Entergy Corporation in March 2020 in anticipation of upcoming expenditures, including Montgomery County Power Station, and the issuance of $175 million of 3.55% Series mortgage bonds in March 2020. The decrease was partially offset by money pool activity.

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 $30.9 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 Texas’s debt to capital ratio is shown in the following table.

	March 31, 2021		December 31, 2020
Debt to capital	52.8	%	53.7	%
Effect of excluding the securitization bonds	(0.9	%)	(1.3	%)
Debt to capital, excluding securitization bonds (a)	51.9	%	52.4	%
Effect of subtracting cash	—	%	(2.7	%)
Net debt to net capital, excluding securitization bonds (a)	51.9	%	49.7	%

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

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Management's Financial Discussion and Analysis

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, 2021	December 31, 2020	March 31, 2020	December 31, 2019
(In Thousands)
($30,858)	$4,601	$29,092	$11,181

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 September 2024.  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, 2021, 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, 2021, $30.2 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.

Liberty County Solar Facility

In September 2020, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to acquire the 100 MW Liberty County Solar Facility and a determination that Entergy Texas’s acquisition of the facility through a tax equity partnership is in the public interest. In its preliminary order, the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s use of a tax equity partnership is in the public interest. In March 2021 intervenors and PUCT staff filed testimony, and Entergy Texas filed rebuttal testimony in April 2021. A hearing on the merits was held in April 2021. Post-hearing briefs and reply briefs are due in May 2021. Closing is expected to occur in 2023.

Hardin County Peaking Facility

In April 2020, Entergy Texas and East Texas Electric Cooperative, Inc. filed a joint report and application seeking PUCT approvals related to two transactions: (1) Entergy Texas’s acquisition of the Hardin County Peaking Facility from East Texas Electric Cooperative, Inc.; and (2) Entergy Texas’s sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. The two transactions, currently

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Management's Financial Discussion and Analysis

expected to close in June 2021, are interdependent. In October 2020, Entergy Texas filed an unopposed settlement agreement supporting approval of the transactions. Key provisions of the settlement include: Entergy Texas will propose to depreciate its investment in Hardin County Peaking Facility through the end of 2041; Entergy Texas’s recovery of its investment in Hardin County Peaking Facility will be capped at approximately $36 million; and Entergy Texas will not seek recovery of an acquisition adjustment, if any, or transaction costs for either transaction. The settlement was approved by the PUCT in April 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.

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

Fuel and purchased power recovery

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

Federal Regulation

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

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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.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING REVENUES
Electric	$480,220	$339,336
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	112,396	41,346
Purchased power	141,362	119,791
Other operation and maintenance	62,955	58,933
Taxes other than income taxes	21,875	19,272
Depreciation and amortization	50,936	42,566
Other regulatory charges (credits) - net	15,840	21,368
TOTAL	405,364	303,276
OPERATING INCOME	74,856	36,060
OTHER INCOME
Allowance for equity funds used during construction	2,445	10,641
Interest and investment income	224	429
Miscellaneous - net	(423)	(346)
TOTAL	2,246	10,724
INTEREST EXPENSE
Interest expense	23,038	22,858
Allowance for borrowed funds used during construction	(984)	(4,573)
TOTAL	22,054	18,285
INCOME BEFORE INCOME TAXES	55,048	28,499
Income taxes	4,990	(4,208)
NET INCOME	50,058	32,707
Preferred dividend requirements	470	470
EARNINGS APPLICABLE TO COMMON STOCK	$49,588	$32,237
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING ACTIVITIES
Net income	$50,058	$32,707
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation and amortization	50,936	42,566
Deferred income taxes, investment tax credits, and non-current taxes accrued	(1,522)	3,921
Changes in assets and liabilities:
Receivables	(16,424)	1,221
Fuel inventory	3,509	(1,127)
Accounts payable	(42,511)	(35,288)
Taxes accrued	(5,123)	(20,597)
Interest accrued	(10,989)	(7,380)
Deferred fuel costs	(62,970)	8,138
Other working capital accounts	1,118	5,004
Provisions for estimated losses	(31)	5
Other regulatory assets	40,484	34,309
Other regulatory liabilities	(13,649)	(8,854)
Pension and other postretirement liabilities	(5,434)	(9,086)
Other assets and liabilities	(16,316)	(8,425)
Net cash flow provided by (used in) operating activities	(28,864)	37,114
INVESTING ACTIVITIES
Construction expenditures	(238,903)	(236,984)
Allowance for equity funds used during construction	2,445	10,641
Changes in money pool receivable - net	4,601	(17,911)
Changes in securitization account	8,161	11,604
Net cash flow used in investing activities	(223,696)	(232,650)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—	194,631
Retirement of long-term debt	(27,951)	(26,864)
Capital contribution from parent	—	175,000
Change in money pool payable - net	30,858	—
Preferred stock dividends paid	(470)	(653)
Other	1,552	206
Net cash flow provided by financing activities	3,989	342,320
Net increase (decrease) in cash and cash equivalents	(248,571)	146,784
Cash and cash equivalents at beginning of period	248,596	12,929
Cash and cash equivalents at end of period	$25	$159,713
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$33,394	$29,699
Income taxes	($836)	($2,358)
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$25	$26
Temporary cash investments	—	248,570
Total cash and cash equivalents	25	248,596
Securitization recovery trust account	28,072	36,233
Accounts receivable:
Customer	108,152	103,221
Allowance for doubtful accounts	(15,058)	(16,810)
Associated companies	14,385	18,892
Other	14,995	11,780
Accrued unbilled revenues	62,845	56,411
Total accounts receivable	185,319	173,494
Fuel inventory - at average cost	50,022	53,531
Materials and supplies - at average cost	60,011	56,227
Prepayments and other	12,493	20,165
TOTAL	335,942	588,246
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity	336	349
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	17,552	19,889
TOTAL	18,264	20,614
UTILITY PLANT
Electric	6,771,662	6,007,687
Construction work in progress	178,917	879,908
TOTAL UTILITY PLANT	6,950,579	6,887,595
Less - accumulated depreciation and amortization	1,898,407	1,864,494
UTILITY PLANT - NET	5,052,172	5,023,101
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $60,618 as of March 31, 2021 and $78,590 as of December 31, 2020)	484,229	524,713
Other	78,654	70,397
TOTAL	562,883	595,110
TOTAL ASSETS	$5,969,261	$6,227,071
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$200,000	$200,000
Accounts payable:
Associated companies	81,613	55,944
Other	139,190	350,947
Customer deposits	33,831	36,282
Taxes accrued	47,315	52,438
Interest accrued	9,867	20,856
Current portion of unprotected excess accumulated deferred income taxes	30,591	29,249
Deferred fuel costs	22,386	85,356
Other	12,377	12,370
TOTAL	577,170	843,442
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	635,212	639,422
Accumulated deferred investment tax credits	9,788	9,942
Regulatory liability for income taxes - net	164,680	175,594
Other regulatory liabilities	28,220	32,297
Asset retirement cost liabilities	8,175	8,063
Accumulated provisions	8,351	8,382
Long-term debt (includes securitization bonds of $95,185 as of March 31, 2021 and $123,066 as of December 31, 2020)	2,265,827	2,293,708
Other	64,672	58,643
TOTAL	3,184,925	3,226,051
Commitments and Contingencies
EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2021 and 2020	49,452	49,452
Paid-in capital	955,162	955,162
Retained earnings	1,167,552	1,117,964
Total common shareholder's equity	2,172,166	2,122,578
Preferred stock without sinking fund	35,000	35,000
TOTAL	2,207,166	2,157,578
TOTAL LIABILITIES AND EQUITY	$5,969,261	$6,227,071
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
			Common Equity
	Preferred Stock		Common Stock		Paid-in Capital		Retained Earnings		Total
	(In Thousands)
Balance at December 31, 2019	$35,000		$49,452		$780,182		$934,773		$1,799,407
Net income	—		—		—		32,707		32,707
Capital contribution from parent	—		—		175,000		—		175,000
Preferred stock dividends	—		—		—		(470)		(470)
Balance at March 31, 2020	$35,000		$49,452		$955,182		$967,010		$2,006,644
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
See Notes to Financial Statements.

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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.

Results of Operations

Net Income

Net income decreased $4.6 million primarily due to a decrease in the allowance for equity funds used during construction resulting from higher spending in 2020 including the scheduled 2020 Grand Gulf refueling outage.

Income Taxes

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 Notes 2 and 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.

The effective income tax rate was 16% for the first quarter 2020. The difference in the effective income tax rate for the first quarter 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items, permanent differences related to income tax deductions for stock-based compensation, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

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Liquidity and Capital Resources

Cash Flow

Cash flows for the three months ended March 31, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Cash and cash equivalents at beginning of period	$242,469	$68,534
Cash flow provided by (used in):
Operating activities	(29,242)	60,442
Investing activities	(23,437)	(79,532)
Financing activities	(57,563)	43,002
Net increase (decrease) in cash and cash equivalents	(110,242)	23,912
Cash and cash equivalents at end of period	$132,227	$92,446

Operating Activities

System Energy’s operating activities used $29.2 million of cash for the three months ended March 31, 2021 compared to providing $60.4 million of cash for the three months ended March 31, 2020 primarily due to income tax payments of $39.1 million in 2021 and timing of payments to vendors, partially offset by a decrease in spending of $18 million on nuclear refueling outages in 2021 as compared to the same period in 2020. 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 decreased $56.1 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020 primarily due to:

•an increase of $67.4 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

•a decrease of $46.4 million in nuclear construction expenditures as a result of spending in 2020 on Grand Gulf outage projects and upgrades.

The decrease was partially offset by money pool activity.

Increases in System Energy’s receivable from the money pool are a use of cash flow and System Energy’s receivable from the money pool increased by $12.7 million for the three months ended March 31, 2021 compared to decreasing by $42.5 million for the three months ended March 31, 2020. 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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Financing Activities

System Energy’s financing activities used $57.6 million of cash for the three months ended March 31, 2021 compared to providing $43 million of cash for the three months ended March 31, 2020 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.

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to the net repayment of long-term debt in 2021.

	March 31, 2021		December 31, 2020
Debt to capital	41.5	%	42.7	%
Effect of subtracting cash	(4.5	%)	(8.5	%)
Net debt to net capital	37.0	%	34.2	%

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, 2021	December 31, 2020	March 31, 2020	December 31, 2019
(In Thousands)
$16,682	$4,004	$16,819	$59,298

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 September 2022. As of March 31, 2021, $63.4 million in loans were outstanding under the 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.

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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 May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. System Energy recorded a provision against revenue for the potential outcome of this proceeding.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

The ALJ initial decision is an interim step in the FERC litigation process. 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 are due in May 2021.

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

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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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance

147

System Energy Resources, Inc.

Management's Financial Discussion and Analysis

indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Nuclear Matters

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

NRC Reactor Oversight Process

As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of associated costs.

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.

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.

148

SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING REVENUES
Electric	$117,746	$130,664
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	16,859	13,143
Nuclear refueling outage expenses	6,718	8,272
Other operation and maintenance	41,960	40,471
Decommissioning	9,529	9,157
Taxes other than income taxes	6,825	7,973
Depreciation and amortization	28,194	26,899
Other regulatory charges (credits) - net	11,550	(10,560)
TOTAL	121,635	95,355
OPERATING INCOME (LOSS)	(3,889)	35,309
OTHER INCOME
Allowance for equity funds used during construction	1,111	3,584
Interest and investment income	27,442	5,338
Miscellaneous - net	(2,024)	(2,460)
TOTAL	26,529	6,462
INTEREST EXPENSE
Interest expense	9,535	8,540
Allowance for borrowed funds used during construction	(188)	(711)
TOTAL	9,347	7,829
INCOME BEFORE INCOME TAXES	13,293	33,942
Income taxes	(10,571)	5,429
NET INCOME	$23,864	$28,513
See Notes to Financial Statements.

149

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150

SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	2021	2020
	(In Thousands)
OPERATING ACTIVITIES
Net income	$23,864	$28,513
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	53,433	47,041
Deferred income taxes, investment tax credits, and non-current taxes accrued	(10,197)	(5,764)
Changes in assets and liabilities:
Receivables	9,255	22,292
Accounts payable	(21,296)	15,049
Taxes accrued	(33,364)	(3,590)
Interest accrued	(1,088)	(201)
Other working capital accounts	2,347	(30,385)
Other regulatory assets	20,923	(3,893)
Other regulatory liabilities	(12,591)	(135,561)
Pension and other postretirement liabilities	(7,424)	(2,587)
Other assets and liabilities	(53,104)	129,528
Net cash flow provided by (used in) operating activities	(29,242)	60,442
INVESTING ACTIVITIES
Construction expenditures	(14,890)	(60,551)
Allowance for equity funds used during construction	1,111	3,584
Nuclear fuel purchases	(4,745)	(69,022)
Proceeds from the sale of nuclear fuel	12,626	9,503
Proceeds from nuclear decommissioning trust fund sales	211,481	132,661
Investment in nuclear decommissioning trust funds	(216,342)	(138,186)
Changes in money pool receivable - net	(12,678)	42,479
Net cash flow used in investing activities	(23,437)	(79,532)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	189,244	243,559
Retirement of long-term debt	(225,807)	(186,904)
Common stock dividends and distributions paid	(21,000)	(13,653)
Net cash flow provided by (used in) financing activities	(57,563)	43,002
Net increase (decrease) in cash and cash equivalents	(110,242)	23,912
Cash and cash equivalents at beginning of period	242,469	68,534
Cash and cash equivalents at end of period	$132,227	$92,446
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$10,720	$8,598
Income taxes	$39,085	$—
See Notes to Financial Statements.

151

SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$78	$26,086
Temporary cash investments	132,149	216,383
Total cash and cash equivalents	132,227	242,469
Accounts receivable:
Associated companies	59,422	57,743
Other	4,294	2,550
Total accounts receivable	63,716	60,293
Materials and supplies - at average cost	126,444	123,006
Deferred nuclear refueling outage costs	27,932	34,459
Prepayments and other	7,605	6,864
TOTAL	357,924	467,091
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,249,846	1,215,868
TOTAL	1,249,846	1,215,868
UTILITY PLANT
Electric	5,310,445	5,309,458
Construction work in progress	73,360	59,831
Nuclear fuel	150,948	175,005
TOTAL UTILITY PLANT	5,534,753	5,544,294
Less - accumulated depreciation and amortization	3,381,583	3,355,367
UTILITY PLANT - NET	2,153,170	2,188,927
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	518,040	538,963
Other	2,441	3,119
TOTAL	520,481	542,082
TOTAL ASSETS	$4,281,421	$4,413,968
See Notes to Financial Statements.

152

SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
March 31, 2021 and December 31, 2020
(Unaudited)
	2021	2020
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$19	$100,015
Accounts payable:
Associated companies	4,644	15,309
Other	36,849	41,313
Taxes accrued	49,613	82,977
Interest accrued	11,634	12,722
Other	4,247	4,248
TOTAL	107,006	256,584
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	340,689	359,835
Accumulated deferred investment tax credits	43,963	38,902
Regulatory liability for income taxes - net	134,350	151,829
Other regulatory liabilities	670,284	665,396
Decommissioning	978,439	968,910
Pension and other postretirement liabilities	117,988	125,412
Long-term debt	768,950	705,259
Other	36,342	61,295
TOTAL	3,091,005	3,076,838
Commitments and Contingencies
COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2021 and 2020	951,850	951,850
Retained earnings	131,560	128,696
TOTAL	1,083,410	1,080,546
TOTAL LIABILITIES AND EQUITY	$4,281,421	$4,413,968
See Notes to Financial Statements.

153

SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Three Months Ended March 31, 2021 and 2020
(Unaudited)
	Common Equity
	Common Stock	Retained Earnings	Total
	(In Thousands)
Balance at December 31, 2019	$601,850	$110,218	$712,068
Net income	—	28,513	28,513
Common stock dividends and distributions	—	(13,653)	(13,653)
Balance at March 31, 2020	$601,850	$125,078	$726,928
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
See Notes to Financial Statements.

154

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

There have been no material changes to the risk factors discussed in “PART I, Item 1A, Risk Factors” in the Form 10-K.

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)
1/01/2021-1/31/2021	—	$—	—	$350,052,918
2/01/2021-2/28/2021	—	$—	—	$350,052,918
3/01/2021-3/31/2021	—	$—	—	$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 2021, Entergy withheld 81,434 shares of its common stock at $95.12 per share, 40,476 shares of its common stock at $95.15 per share, 36,804 shares of its common stock at $94.75 per share, 36,347 shares of its common stock at $95.33 per share, 1,188 shares of its common stock at $91.16 per share, 853 shares of its common stock at $96.47 per share, 719 shares of its common stock at $98.01 per share, 678 shares of its common stock at $92.70 per share, 584 shares of its common stock at $94.69 per share, 118 shares of its common stock at $95 per share, and 10 shares of its common stock at $95.25 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.

155

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 2021 filings with the NRC were made reporting on decommissioning funding for all of Entergy subsidiaries’ nuclear plants.  Those reports showed that decommissioning funding for each of the nuclear plants met the NRC’s financial assurance requirements.

NRC Reactor Oversight Process

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.

Environmental Regulation

Following are updates to the “Environmental Regulation” section of Part I, Item 1 of the Form 10-K.

Clean Air Act and Subsequent Amendments

See the Form 10-K for discussion of the Clean Air Act and Subsequent Amendments set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.

New Source Review

As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims as well as other issues facing Entergy Arkansas’s fossil generation plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In March 2021 the District Court approved and entered the proposed settlement. For further information about the settlement, see “Regional Haze” discussed below.

National Ambient Air Quality Standards

See the Form 10-K for discussion of the National Ambient Air Quality Standards set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.

156

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. The EPA must file status reports with the court every 120 days. Entergy will continue to monitor this situation.

Cross-State Air Pollution

As discussed in the Form 10-K, for 12 states, including Louisiana, the EPA proposes additional emission reductions through proposed reductions in the number of NOx emission allowances allocated to each state. Entergy, through its various trade associations, filed comments on the proposal. In March 2021 the EPA released the prepublication version of the final rule which further decreases the Louisiana ozone season emissions budget from that in the proposed rule. Entergy is currently analyzing the potential impact on its facilities in Louisiana. Preliminary analysis indicates that ozone season NOx allowances may become significantly more expensive in Louisiana, which could impact the cost of dispatching Entergy’s generating units located in Louisiana.

Regional Haze

As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims and reducing the risk that Entergy Arkansas, as operator of Independence and White Bluff, might be compelled under the Clean Air Act’s regional haze program to install costly emissions control technologies. Consistent with the terms of the settlement and in many cases also the Part II state implementation plan (SIP), Entergy Arkansas, along with co-owners, will begin using only low-sulfur coal at Independence and White Bluff by mid-2021; cease to use coal at White Bluff and Independence by the end of 2028 and 2030, respectively; cease operation of the remaining gas unit at Lake Catherine by the end of 2027; reserve the option to develop new generating sources at each plant site; and commit to install or propose to regulators at least 800 MWs of renewable generation by the end of 2027, with at least half installed or proposed by the end of 2022 (which includes two existing Entergy Arkansas projects) and with all qualifying co-owner projects counting toward satisfaction of the obligation. Under the settlement, the Sierra Club and the National Parks Conservation Association also waive certain potential existing claims under federal and state environmental law with respect to specified generating plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In November 2020 the court denied motions by the Arkansas Attorney General and the Arkansas Affordable Energy Coalition to intervene and to stay the proceedings. The proposed intervenors did not appeal the ruling. The District Court approved and entered the proposed settlement in March 2021.

The second planning period (2018-2028) for the regional haze program requires states to examine sources for impacts on visibility and to prepare SIPs by July 31, 2021. Entergy has received information collection requests from Arkansas and Louisiana requesting an evaluation of technical and economic feasibility of various NOx and SO2 control technologies for Independence, Nelson 6, and Ninemile. Responses to the information requests have been submitted to the respective state agencies.

157

New and Existing Source Performance Standards for Greenhouse Gas Emissions

As discussed in the Form 10-K, in January 2021 the U.S. Court of Appeals for the D.C. Circuit vacated the Affordable Clean Energy Rule (ACE). The court held that ACE relied on an incorrect interpretation of the Clean Air Act that the statute expressly forecloses emission reduction approaches, such as emissions trading and generating shifting, that cannot be applied at and to the individual source. The court remanded ACE to the EPA for further consideration and also vacated the repeal of the Clean Power Plan. In March 2021 the D.C. Circuit issued a partial mandate vacating the ACE rule, but withheld the mandate vacating the repeal of the Clean Power Plan pending the EPA’s new rulemaking to regulate greenhouse gas emissions. Thus, the Clean Power Plan will not take effect during the rulemaking process and there currently is no regulation in place with respect to greenhouse gas emissions from electric generating units and states are not expected to take further action to develop and submit plans at this time.

Coal Combustion Residuals

As discussed in the Form 10-K, in late 2017, Entergy determined that certain in-ground wastewater treatment system recycle ponds at its White Bluff and Independence facilities require management under the new EPA regulations. Each site has commenced closure of its two recycle ponds (four ponds total), prior to the April 11, 2021 deadline under the finalized CCR rule for unlined recycle ponds.

Other Environmental Matters

Entergy Texas

As discussed in the Form 10-K, due to COVID-19 pandemic delays, the Texas Commission on Environmental Quality (TCEQ) extended the Affected Property Assessment Report (APAR) and Ecological Risk Assessment submittal dates to December 2020, which Entergy timely met. Following the TCEQ’s review of the APAR and Ecological Risk Assessment, the TCEQ issued a No Further Action determination for the site in March 2021.

Item 6.  Exhibits

4(a) -	Officer’s Certificate for Entergy Corporation relating to 1.90% Senior Notes due June 15, 2028 (4.02(a) to Form 8-K filed March 5, 2021 in 1-11299).
4(b) -	Officer’s Certificate for Entergy Corporation relating to 2.40% Senior Notes due June 15, 2031 (4.02(b) to Form 8-K filed March 5, 2021 in 1-11299).
4(c) -	Eighty-fourth Supplemental Indenture, dated as of March 1, 2021, to Entergy Arkansas Mortgage and Deed of Trust, dated as of October 1, 1944 (4.49 to Form 8-K filed March 30, 2021 in 1-10764).
4(d) -	Ninety-fifth Supplemental Indenture, dated as of March 1, 2021, to Entergy Louisiana Mortgage and Deed of Trust, dated as of April 1, 1944 (4.53 to Form 8-K filed March 10, 2021 in 1-32718).
4(e) -	Ninety-fourth Supplemental Indenture, dated as of March 1, 2021, to Entergy Louisiana Indenture of Mortgage, dated September 1, 1926 (4.52 to Form 8-K filed March 10, 2021 in 1-32718).
4(f) -	Fifteenth Supplemental Indenture, dated as of March 1, 2021, to Entergy Louisiana Mortgage and Deed of Trust, dated as of November 1, 2015 (4.51 to Form 8-K filed March 10, 2021 in 1-32718).
4(g) -	Sixteenth Supplemental Indenture, dated as of April 1, 2021, to Entergy Louisiana Mortgage and Deed of Trust, dated as of November 1, 2015 (4(b) to Form 8-K filed April 1, 2021 in 1-32718).

158

4(h) -	Officer’s Certificate No. 21-B-15, dated March 1, 2021, supplemental to Mortgage and Deed of Trust of Entergy Louisiana, dated as of November 1, 2015 (4.50(a) to Form 8-K filed March 10, 2021 in 1-32718).
4(i) -	Officer’s Certificate No. 21-B-16, dated March 1, 2021, supplemental to Mortgage and Deed of Trust of Entergy Louisiana, dated as of November 1, 2015 (4.50(b) to Form 8-K filed March 10, 2021 in 1-32718).
4(j) -	Officer’s Certificate No. 22-B-17, dated April 1, 2021, supplemental to Mortgage and Deed of Trust of Entergy Louisiana, dated as of November 1, 2015 (4(a) to Form 8-K filed April 1, 2021 in 1-32718).
4(k) -	Loan Agreement, dated as of April 1, 2021, between the Louisiana Local Government Environmental Facilities and Community Development Authority and Entergy Louisiana relating to Revenue Refunding Bonds (Entergy Louisiana, LLC Project) Series 2021A (4(c) to Form 8-K filed April 1, 2021 in 1-32718).
4(l) -	Trust Indenture, dated as of April 1, 2021, between the Louisiana Local Government Environmental Facilities and Community Development Authority and The Bank of New York Mellon authorizing Revenue Refunding Bonds (Entergy Louisiana, LLC Project) Series 2021A (4(d) to Form 8-K filed April 1, 2021 in 1-32718).
4(m) -	Loan Agreement, dated as of April 1, 2021, between the Louisiana Local Government Environmental Facilities and Community Development Authority and Entergy Louisiana relating to Revenue Refunding Bonds (Entergy Louisiana, LLC Project) Series 2021B (4(e) to Form 8-K filed April 1, 2021 in 1-32718).
4(n) -	Trust Indenture, dated as of April 1, 2021, between the Louisiana Local Government Environmental Facilities and Community Development Authority and The Bank of New York Mellon authorizing Revenue Refunding Bonds (Entergy Louisiana, LLC Project) Series 2021B (4(f) to Form 8-K filed April 1, 2021 in 1-32718).
*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.

159

**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.
99(a) -	Equity Distribution Sales Agreement, dated January 11, 2021 by and among Entergy Corporation and BofA Securities, Inc., Citigroup Global Markets Inc., J.P. Morgan Securities LLC, Mizuho Securities USA LLC and Wells Fargo Securities, LLC, as sales agents and as forward sellers, and Bank of America, N.A., Citibank, N.A., JPMorgan Chase Bank, National Association, New York Branch, Mizuho Markets Americas LLC (with Mizuho Securities USA LLC acting as agent) and Wells Fargo Bank, National Association, as forward purchasers (1.01 to Form 8-K filed January 11, 2021 in 1-11299).
99(b) -	Master Forward Confirmation, dated January 11, 2021, between Entergy Corporation and Bank of America, N.A. (99.01 to Form 8-K filed January 11, 2021 in 1-11299).
99(c) -	Master Forward Confirmation, dated January 11, 2021, between Entergy Corporation and Citigroup Global Markets Inc. (99.02 to Form 8-K filed January 11, 2021 in 1-11299).
99(d) -	Master Forward Confirmation, dated January 11, 2021, between Entergy Corporation and JPMorgan Chase Bank, National Association (99.03 to Form 8-K filed January 11, 2021 in 1-11299).
99(e) -	Master Forward Confirmation, dated January 11, 2021, between Entergy Corporation and Mizuho Markets Americas LLC (with Mizuho Securities USA LLC acting as agent) (99.04 to Form 8-K filed January 11, 2021 in 1-11299).
99(f) -	Master Forward Confirmation, dated January 11, 2021, between Entergy Corporation and Wells Fargo Bank, National Association (99.05 to Form 8-K filed January 11, 2021 in 1-11299).
*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.
*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.

160

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 6, 2021

161

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 6, 2021

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 6, 2021

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 6, 2021

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 6, 2021

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 6, 2021

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 6, 2021

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 6, 2021

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 6, 2021

EX-31.I

Exhibit 31(i)

CERTIFICATIONS

I, David D. Ellis, 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/ David D. Ellis

David D. Ellis

Chairman of the Board, President, and Chief Executive Officer

of Entergy New Orleans, LLC

Date:  May 6, 2021

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 6, 2021

EX-31.K

Exhibit 31(k)

CERTIFICATIONS

I, Sallie T. Rainer, 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/ Sallie T. Rainer

Sallie T. Rainer

Chair of the Board, President, and Chief Executive Officer

of Entergy Texas, Inc.

Date:  May 6, 2021

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 6, 2021

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 6, 2021

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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, David D. Ellis, Chairman 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, 2021 (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/ David D. Ellis

David D. Ellis

Chairman of the Board, President, and Chief Executive

Officer of Entergy New Orleans, LLC

Date: May 6, 2021

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, 2021 (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 6, 2021

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, Sallie T. Rainer, Chair 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, 2021 (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/ Sallie T. Rainer

Sallie T. Rainer

Chair of the Board, President, and Chief Executive Officer

of Entergy Texas, Inc.

Date: May 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

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, 2021 (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 6, 2021

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2021	Apr. 30, 2021
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, 2021
Amendment Flag	false
Document Fiscal Year Focus	2021
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		200,659,948
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	10055 Grogans Mill Road
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)

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Consolidated Statements Of Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,844,838	$ 2,427,179
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	501,167	397,403
Nuclear refueling outage expenses	43,739	50,218
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	706,786	702,084
Asset Impairment Charges	3,273	5,095
Decommissioning	98,642	93,684
Taxes, Other	156,702	170,294
Other Depreciation and Amortization	414,519	399,710
Other regulatory charges (credits) - net	32,279	(7,679)
Costs and Expenses	2,336,841	2,027,423
OPERATING INCOME	507,997	399,756
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	14,577	35,953
Investment Income, Net	143,315	(216,853)
Miscellaneous - net	(60,929)	23,389
TOTAL	96,963	(157,511)
INTEREST EXPENSE
Interest Expense, Debt	205,886	205,589
Allowance for borrowed funds used during construction	(6,013)	(15,444)
TOTAL	199,873	190,145
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	405,087	52,100
Income taxes	65,942	(71,194)
Consolidated net income	339,145	123,294
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	$ 4,580	$ 4,580
Earnings per average common share:
Basic (in dollars per share)	$ 1.67	$ 0.59
Diluted (in dollars per share)	$ 1.66	$ 0.59
Basic average number of common shares outstanding (in shares)	200,525,549	199,790,016
Diluted average number of common shares outstanding (in shares)	201,059,665	200,901,349
Net Income (Loss) Available to Common Stockholders, Basic	$ 334,565	$ 118,714
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	2,538,420	2,050,638
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	58,168	43,976
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	248,250	332,565
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	379,734	216,614
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	336,619	293,922
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	60,197	63,297
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	67,831	62,337
Taxes, Other	25,899	27,190
Other Depreciation and Amortization	55,036	51,155
Other regulatory charges (credits) - net	8,129	(3,881)
Costs and Expenses	285,683	252,741
OPERATING INCOME	50,936	41,181
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	1,668	1,439
Investment Income, Net	42	120
Miscellaneous - net	(2,313)	(2,296)
TOTAL	(603)	(737)
INTEREST EXPENSE
Interest Expense, Debt	17,613	16,583
Allowance for borrowed funds used during construction	(677)	(551)
TOTAL	16,936	16,032
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	33,397	24,412
Income taxes	7,425	1,886
Consolidated net income	25,972	22,526
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	336,619	293,922
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	68,591	52,643
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	583,386	481,912
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	126,181	87,411
Nuclear refueling outage expenses	12,647	16,247
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	154,908	151,857
Decommissioning	19,000	17,941
Taxes, Other	29,743	31,060
Other Depreciation and Amortization	88,279	83,521
Other regulatory charges (credits) - net	(37,467)	(20,001)
Costs and Expenses	463,512	414,077
OPERATING INCOME	119,874	67,835
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	2,993	2,917
Investment Income, Net	27,887	7,938
Miscellaneous - net	(5,791)	(6,436)
TOTAL	25,089	4,419
INTEREST EXPENSE
Interest Expense, Debt	33,786	35,623
Allowance for borrowed funds used during construction	(1,290)	(1,281)
TOTAL	32,496	34,342
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	112,467	37,912
Income taxes	19,430	(6,683)
Consolidated net income	93,037	44,595
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	583,386	481,912
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	70,221	46,041
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,107,644	930,647
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	145,234	144,492
Nuclear refueling outage expenses	13,282	13,630
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	237,483	222,658
Decommissioning	16,823	16,001
Taxes, Other	52,484	50,077
Other Depreciation and Amortization	160,813	145,135
Other regulatory charges (credits) - net	31,097	11,132
Costs and Expenses	867,177	763,868
OPERATING INCOME	240,467	166,779
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	6,101	14,887
Investment Income, Net	72,515	(19,669)
Miscellaneous - net	(34,638)	49,601
TOTAL	43,978	44,819
INTEREST EXPENSE
Interest Expense, Debt	82,806	79,517
Allowance for borrowed funds used during construction	(2,759)	(7,132)
TOTAL	80,047	72,385
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	204,398	139,213
Income taxes	37,772	(50,183)
Consolidated net income	166,626	189,396
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	166,626	189,396
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,079,663	912,541
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	27,981	18,106
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	209,961	160,743
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	169,335	149,302
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	19,012	27,495
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	38,178	30,704
Taxes, Other	12,556	13,206
Other Depreciation and Amortization	18,161	15,075
Other regulatory charges (credits) - net	3,130	(5,736)
Costs and Expenses	159,707	137,211
OPERATING INCOME	9,628	12,091
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	258	2,485
Investment Income, Net	9	53
Miscellaneous - net	(302)	(738)
TOTAL	(35)	1,800
INTEREST EXPENSE
Interest Expense, Debt	7,029	6,640
Allowance for borrowed funds used during construction	(116)	(1,195)
TOTAL	6,913	5,445
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	2,680	8,446
Income taxes	909	(2,740)
Consolidated net income	1,771	11,186
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	139,148	123,431
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	30,187	25,871
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	68,670	56,467
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	480,220	339,336
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	112,396	41,346
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	62,955	58,933
Taxes, Other	21,875	19,272
Other Depreciation and Amortization	50,936	42,566
Other regulatory charges (credits) - net	15,840	21,368
Costs and Expenses	405,364	303,276
OPERATING INCOME	74,856	36,060
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	2,445	10,641
Investment Income, Net	224	429
Miscellaneous - net	(423)	(346)
TOTAL	2,246	10,724
INTEREST EXPENSE
Interest Expense, Debt	23,038	22,858
Allowance for borrowed funds used during construction	(984)	(4,573)
TOTAL	22,054	18,285
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	55,048	28,499
Income taxes	4,990	(4,208)
Consolidated net income	50,058	32,707
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	470	470
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	49,588	32,237
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	480,220	339,336
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	141,362	119,791
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	16,859	13,143
Nuclear refueling outage expenses	6,718	8,272
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	41,960	40,471
Decommissioning	9,529	9,157
Taxes, Other	6,825	7,973
Other Depreciation and Amortization	28,194	26,899
Other regulatory charges (credits) - net	11,550	(10,560)
Costs and Expenses	121,635	95,355
OPERATING INCOME	(3,889)	35,309
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	1,111	3,584
Investment Income, Net	27,442	5,338
Miscellaneous - net	(2,024)	(2,460)
TOTAL	26,529	6,462
INTEREST EXPENSE
Interest Expense, Debt	9,535	8,540
Allowance for borrowed funds used during construction	(188)	(711)
TOTAL	9,347	7,829
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	13,293	33,942
Income taxes	(10,571)	5,429
Consolidated net income	23,864	28,513
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	23,864	28,513
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 117,746	$ 130,664

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Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
OPERATING ACTIVITIES
Consolidated net income	$ 339,145	$ 123,294
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	580,571	568,596
Deferred income taxes, investment tax credits, and non-current taxes accrued	240,431	(31,405)
Impairment of Long-Lived Assets Held-for-use	3,278	4,962
Changes in working capital:
Receivables	(52,690)	70,357
Fuel inventory	26,878	(15,389)
Accounts payable	(175,651)	(127,727)
Taxes accrued	(231,182)	(44,241)
Interest accrued	(3,778)	(4,791)
Deferred fuel costs	(353,099)	30,560
Other working capital accounts	(43,582)	(21,758)
Changes in provisions for estimated losses	(60,923)	(35,829)
Changes in other regulatory assets	89,910	99,275
Increase (Decrease) in Regulatory Liabilities	(14,464)	(450,905)
Changes in pension and other postretirement liabilities	(166,733)	(113,071)
Other Noncash Income (Expense)	(227,676)	607,132
Net cash flow provided by (used in) operating activities	(49,565)	659,060
INVESTING ACTIVITIES
Construction/capital expenditures	(1,552,103)	(1,043,608)
Allowance for equity funds used during construction	14,577	35,953
Payments to Acquire Buildings	0	(24,633)
Nuclear fuel purchases	(47,916)	(85,334)
Payments for Nuclear Fuel	(47,916)	(85,334)
Payments to storm reserve escrow account	(10)	(1,557)
Receipts from storm reserve escrow account	44,205	40,589
Decrease in other investments	12,521	2,265
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	15,735	62,162
Proceeds from nuclear decommissioning trust fund sales	3,225,510	687,487
Investment in nuclear decommissioning trust funds	(3,224,487)	(718,741)
Changes in securitization account	(1,304)	(70)
Net cash flow used in investing activities	(1,513,272)	(1,045,487)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	3,676,242	3,195,345
Proceeds from Sale of Treasury Stock	979	39,964
Retirement of long-term debt	(1,346,172)	(1,614,578)
Changes in credit borrowings and commercial paper - net	(599,860)	(4,911)
Dividends paid:
Common stock	(190,595)	(185,763)
Other	10,380	(756)
Net cash flow provided by financing activities	1,546,394	1,424,538
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(16,443)	1,038,111
Cash and cash equivalents at beginning of period	1,759,099	425,722
Cash and cash equivalents at end of period	1,742,656	1,463,833
Cash paid / (received) during the period for:
Interest - net of amount capitalized	202,451	203,466
Income taxes	9,015	(23,063)
Dividends Paid, Preferred Stock	(4,580)	(4,763)
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income	93,037	44,595
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	126,630	123,160
Deferred income taxes, investment tax credits, and non-current taxes accrued	42,885	8,251
Changes in working capital:
Receivables	(56,256)	32,820
Fuel inventory	17,930	(9,419)
Accounts payable	(21,622)	(42,694)
Taxes accrued	8,365	9,302
Interest accrued	18,837	16,839
Deferred fuel costs	(55,704)	23,594
Other working capital accounts	(8,025)	(2,691)
Changes in provisions for estimated losses	(12,383)	4,695
Changes in other regulatory assets	42,388	(13,187)
Increase (Decrease) in Regulatory Liabilities	(38,604)	(161,989)
Changes in pension and other postretirement liabilities	(25,116)	11,704
Other Noncash Income (Expense)	(40,789)	164,694
Net cash flow provided by (used in) operating activities	91,573	209,674
INVESTING ACTIVITIES
Construction/capital expenditures	(146,334)	(179,117)
Allowance for equity funds used during construction	2,993	2,917
Nuclear fuel purchases	(17,621)	(52,211)
Payments for Nuclear Fuel	(17,621)	(52,211)
Proceeds from sale of nuclear fuel	16,059	17,210
Change in money pool receivable - net	(12,500)	(24,935)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	0	55,001
Proceeds from nuclear decommissioning trust fund sales	143,575	115,030
Investment in nuclear decommissioning trust funds	(148,783)	(121,003)
Changes in securitization account	0	(3,443)
Net cash flow used in investing activities	(162,611)	(190,551)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	604,760	264,505
Retirement of long-term debt	(613,706)	(127,203)
Change in money pool payable - net	0	(21,634)
Dividends paid:
Other	11,636	(818)
Net cash flow provided by financing activities	2,690	114,850
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(68,348)	133,973
Cash and cash equivalents at beginning of period	192,128	3,519
Cash and cash equivalents at end of period	123,780	137,492
Cash paid / (received) during the period for:
Interest - net of amount capitalized	14,359	17,578
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income	166,626	189,396
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	198,868	191,447
Deferred income taxes, investment tax credits, and non-current taxes accrued	67,823	(39,681)
Changes in working capital:
Receivables	(13,080)	23,004
Fuel inventory	1,194	(456)
Accounts payable	(126,070)	(86,317)
Taxes accrued	20,619	48,840
Interest accrued	(9,163)	(2,384)
Deferred fuel costs	(203,815)	(18,280)
Other working capital accounts	(25,628)	(3,156)
Changes in provisions for estimated losses	(258)	(41,113)
Changes in other regulatory assets	(70,784)	55,539
Increase (Decrease) in Regulatory Liabilities	22,503	(129,370)
Changes in pension and other postretirement liabilities	(30,745)	(22,806)
Other Noncash Income (Expense)	(52,688)	149,136
Net cash flow provided by (used in) operating activities	(54,598)	313,799
INVESTING ACTIVITIES
Construction/capital expenditures	(945,831)	(344,522)
Allowance for equity funds used during construction	6,101	14,887
Nuclear fuel purchases	(52,435)	(18,052)
Payments for Nuclear Fuel	(52,435)	(18,052)
Proceeds from sale of nuclear fuel	0	33,889
Change in money pool receivable - net	(62,346)	(84,466)
Payments to storm reserve escrow account	0	(1,113)
Receipts from storm reserve escrow account	0	40,589
Proceeds from nuclear decommissioning trust fund sales	291,275	144,962
Investment in nuclear decommissioning trust funds	(329,180)	(154,065)
Changes in securitization account	(6,050)	(5,348)
Net cash flow used in investing activities	(1,098,466)	(373,239)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	1,399,245	1,221,900
Retirement of long-term debt	(368,707)	(603,607)
Change in money pool payable - net	0	(82,826)
Dividends paid:
Common stock	0	(11,500)
Other	(3,678)	(1,139)
Net cash flow provided by financing activities	1,026,860	522,828
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(126,204)	463,388
Cash and cash equivalents at beginning of period	728,020	2,006
Cash and cash equivalents at end of period	601,816	465,394
Cash paid / (received) during the period for:
Interest - net of amount capitalized	89,432	79,794
Income taxes	0	(20,684)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income	25,972	22,526
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	55,036	51,155
Deferred income taxes, investment tax credits, and non-current taxes accrued	22,593	2,762
Changes in working capital:
Receivables	4,557	17,971
Fuel inventory	1,736	(3,266)
Accounts payable	26,391	(8,125)
Taxes accrued	(75,886)	(58,651)
Interest accrued	4,238	6,201
Deferred fuel costs	(25,722)	13,406
Other working capital accounts	(3,425)	7,849
Changes in provisions for estimated losses	(7,689)	(47)
Changes in other regulatory assets	11,015	(8,484)
Increase (Decrease) in Regulatory Liabilities	19,147	(5,532)
Changes in pension and other postretirement liabilities	(5,668)	(2,482)
Other Noncash Income (Expense)	2,016	(2,022)
Net cash flow provided by (used in) operating activities	54,311	33,261
INVESTING ACTIVITIES
Construction/capital expenditures	(154,788)	(124,986)
Allowance for equity funds used during construction	1,668	1,439
Payments to Acquire Buildings	0	(24,633)
Change in money pool receivable - net	(9,683)	44,693
Decrease in other investments	1	(128)
Net cash flow used in investing activities	(162,802)	(103,615)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	200,573	0
Change in money pool payable - net	(16,516)	19,006
Dividends paid:
Common stock	0	(2,500)
Other	1,132	2,266
Net cash flow provided by financing activities	185,189	18,772
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	76,698	(51,582)
Cash and cash equivalents at beginning of period	18	51,601
Cash and cash equivalents at end of period	76,716	19
Cash paid / (received) during the period for:
Interest - net of amount capitalized	12,757	9,800
Income taxes	(8,045)	0
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income	1,771	11,186
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	18,161	15,075
Deferred income taxes, investment tax credits, and non-current taxes accrued	4,572	1,339
Changes in working capital:
Receivables	(1,975)	4,039
Fuel inventory	2,234	(25)
Accounts payable	(27,777)	(5,291)
Taxes accrued	13	122
Interest accrued	(3,203)	(929)
Deferred fuel costs	(4,886)	3,702
Other working capital accounts	(11,103)	(10,795)
Changes in provisions for estimated losses	(40,680)	923
Changes in other regulatory assets	28,879	1,867
Increase (Decrease) in Regulatory Liabilities	8,728	(9,599)
Changes in pension and other postretirement liabilities	(4,397)	(4,878)
Other Noncash Income (Expense)	15,549	10,582
Net cash flow provided by (used in) operating activities	(14,114)	17,318
INVESTING ACTIVITIES
Construction/capital expenditures	(26,165)	(60,001)
Allowance for equity funds used during construction	258	2,485
Change in money pool receivable - net	0	(7,979)
Payments to storm reserve escrow account	(3)	(314)
Receipts from storm reserve escrow account	44,200	0
Changes in securitization account	(3,415)	(2,882)
Net cash flow used in investing activities	14,875	(68,691)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	0	139,116
Retirement of long-term debt	0	(20,000)
Change in money pool payable - net	15,039	0
Dividends paid:
Other	(214)	(445)
Net cash flow provided by financing activities	14,825	118,671
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	15,586	67,298
Cash and cash equivalents at beginning of period	26	6,017
Cash and cash equivalents at end of period	15,612	73,315
Cash paid / (received) during the period for:
Interest - net of amount capitalized	9,921	7,275
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income	50,058	32,707
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	50,936	42,566
Deferred income taxes, investment tax credits, and non-current taxes accrued	(1,522)	3,921
Changes in working capital:
Receivables	(16,424)	1,221
Fuel inventory	3,509	(1,127)
Accounts payable	(42,511)	(35,288)
Taxes accrued	(5,123)	(20,597)
Interest accrued	(10,989)	(7,380)
Deferred fuel costs	(62,970)	8,138
Other working capital accounts	1,118	5,004
Changes in provisions for estimated losses	(31)	5
Changes in other regulatory assets	40,484	34,309
Increase (Decrease) in Regulatory Liabilities	(13,649)	(8,854)
Changes in pension and other postretirement liabilities	(5,434)	(9,086)
Other Noncash Income (Expense)	(16,316)	(8,425)
Net cash flow provided by (used in) operating activities	(28,864)	37,114
INVESTING ACTIVITIES
Construction/capital expenditures	(238,903)	(236,984)
Allowance for equity funds used during construction	2,445	10,641
Change in money pool receivable - net	4,601	(17,911)
Changes in securitization account	8,161	11,604
Net cash flow used in investing activities	(223,696)	(232,650)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	0	194,631
Retirement of long-term debt	(27,951)	(26,864)
Change in money pool payable - net	30,858	0
Dividends paid:
Other	1,552	206
Net cash flow provided by financing activities	3,989	342,320
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(248,571)	146,784
Cash and cash equivalents at beginning of period	248,596	12,929
Cash and cash equivalents at end of period	25	159,713
Cash paid / (received) during the period for:
Interest - net of amount capitalized	33,394	29,699
Income taxes	(836)	(2,358)
Proceeds from Contributions from Parent	0	175,000
Dividends Paid, Preferred Stock	(470)	(653)
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income	23,864	28,513
Adjustments to reconcile consolidated net income to net cash flow provided by (used in) operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	53,433	47,041
Deferred income taxes, investment tax credits, and non-current taxes accrued	(10,197)	(5,764)
Changes in working capital:
Receivables	9,255	22,292
Accounts payable	(21,296)	15,049
Taxes accrued	(33,364)	(3,590)
Interest accrued	(1,088)	(201)
Other working capital accounts	2,347	(30,385)
Changes in other regulatory assets	20,923	(3,893)
Increase (Decrease) in Regulatory Liabilities	(12,591)	(135,561)
Changes in pension and other postretirement liabilities	(7,424)	(2,587)
Other Noncash Income (Expense)	(53,104)	129,528
Net cash flow provided by (used in) operating activities	(29,242)	60,442
INVESTING ACTIVITIES
Construction/capital expenditures	(14,890)	(60,551)
Allowance for equity funds used during construction	1,111	3,584
Nuclear fuel purchases	(4,745)	(69,022)
Payments for Nuclear Fuel	(4,745)	(69,022)
Proceeds from sale of nuclear fuel	12,626	9,503
Change in money pool receivable - net	(12,678)	42,479
Proceeds from nuclear decommissioning trust fund sales	211,481	132,661
Investment in nuclear decommissioning trust funds	(216,342)	(138,186)
Net cash flow used in investing activities	(23,437)	(79,532)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	189,244	243,559
Retirement of long-term debt	(225,807)	(186,904)
Dividends paid:
Common stock	(21,000)	(13,653)
Net cash flow provided by financing activities	(57,563)	43,002
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(110,242)	23,912
Cash and cash equivalents at beginning of period	242,469	68,534
Cash and cash equivalents at end of period	132,227	92,446
Cash paid / (received) during the period for:
Interest - net of amount capitalized	10,720	8,598
Income taxes	$ 39,085	$ 0

XML

Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Cash and cash equivalents:
Cash	$ 67,574	$ 128,851
Temporary cash investments	1,675,082	1,630,248
Total cash and cash equivalents	1,742,656	1,759,099
Securitization recovery trust account	44,000	42,000
Accounts receivable:
Customer	883,352	833,478
Allowance for doubtful accounts	(119,027)	(117,794)
Other	158,838	135,208
Accrued unbilled revenues	415,253	434,835
Total accounts receivable	1,338,416	1,285,727
Deferred Fuel Cost	226,619	4,380
Fuel inventory - at average cost	146,056	172,934
Public Utilities, Inventory	972,771	962,185
Deferred nuclear refueling outage costs	182,721	179,150
Prepaid Expense and Other Assets, Current	179,315	196,424
TOTAL	4,788,554	4,559,899
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	7,339,088	7,253,215
Non-utility property - at cost (less accumulated depreciation)	355,819	343,328
Other	169,094	214,222
TOTAL	7,864,001	7,810,765
PROPERTY, PLANT, AND EQUIPMENT
Electric	60,901,229	59,696,443
Natural gas	621,682	610,768
Construction work in progress	1,311,997	2,012,030
Nuclear fuel	591,124	601,281
TOTAL PROPERTY, PLANT, AND EQUIPMENT	63,426,032	62,920,522
Less - accumulated depreciation and amortization	24,403,999	24,067,745
PROPERTY, PLANT, AND EQUIPMENT - NET	39,022,033	38,852,777
Regulatory assets:
Other regulatory assets	5,986,639	6,076,549
Deferred Fuel Cost Non Current	240,555	240,422
Goodwill	377,172	377,172
Deferred Income Tax Assets, Net	56,068	76,289
Other	332,606	245,339
Deferred Costs and Other Assets	6,993,040	7,015,771
TOTAL ASSETS	58,667,628	58,239,212
CURRENT LIABILITIES
Currently maturing long-term debt	629,019	1,164,015
Short-term borrowings	1,027,629	1,627,489
Accounts payable	1,697,206	2,739,437
Taxes Payable, Current	209,829	441,011
Interest accrued	198,013	201,791
Deferred fuel costs	22,386	153,113
Pension and other postretirement liabilities	63,752	61,815
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	65,056	63,683
Other	207,984	206,640
TOTAL	4,511,906	7,060,506
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,568,106	4,361,772
Accumulated deferred investment tax credits	217,888	212,494
Regulatory liability for income taxes - net	1,465,852	1,521,757
Other regulatory liabilities	2,363,919	2,323,851
Decommissioning and asset retirement cost liabilities	6,528,450	6,469,452
Loss Contingency Accrual	181,912	242,835
Pension and other postretirement liabilities	2,684,343	2,853,013
Long-term debt	24,075,456	21,205,761
Deferred Credits and Other Liabilities	798,210	807,219
TOTAL	$ 42,884,136	$ 39,998,154
Common Stock, Shares, Issued	270,035,180	270,035,180
Subsidiaries' preferred stock without sinking fund	$ 219,410	$ 219,410
Common Shareholders' Equity:
Common Stock, Value, Issued	2,700	2,700
Additional Paid in Capital, Common Stock	6,520,052	6,549,923
Accumulated other comprehensive loss	$ (500,507)	$ (449,207)
Treasury Stock, Shares	69,402,016	69,790,346
Less - treasury stock, at cost	$ 5,046,221	$ 5,074,456
TOTAL	11,017,176	10,926,142
Stockholders' Equity Attributable to Noncontrolling Interest	35,000	35,000
Retained Earnings (Accumulated Deficit)	10,041,152	9,897,182
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	11,052,176	10,961,142
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	58,667,628	58,239,212
Long-term Transition Bond, Noncurrent	$ 146,881	$ 174,635
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Securitized Regulatory Transition Assets, Noncurrent	$ 92,585	$ 119,238
Contract with Customer, Liability, Current	$ 391,032	$ 401,512
Common Stock, Shares Authorized	500,000,000	500,000,000
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	$ 122	$ 24,108
Temporary cash investments	123,658	168,020
Total cash and cash equivalents	123,780	192,128
Accounts receivable:
Customer	215,233	183,719
Allowance for doubtful accounts	(21,176)	(18,334)
Associated companies	56,711	34,216
Other	69,110	35,845
Accrued unbilled revenues	93,324	109,000
Total accounts receivable	413,202	344,446
Deferred Fuel Cost	2,506	0
Fuel inventory - at average cost	25,881	43,811
Public Utilities, Inventory	243,721	237,640
Deferred nuclear refueling outage costs	26,613	32,692
Prepaid Expense and Other Assets, Current	15,134	13,296
TOTAL	850,837	864,013
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,311,053	1,273,921
Other	340	341
TOTAL	1,311,393	1,274,262
PROPERTY, PLANT, AND EQUIPMENT
Electric	12,963,731	12,905,322
Construction work in progress	288,269	234,213
Nuclear fuel	143,835	163,044
TOTAL PROPERTY, PLANT, AND EQUIPMENT	13,395,835	13,302,579
Less - accumulated depreciation and amortization	5,323,933	5,255,355
PROPERTY, PLANT, AND EQUIPMENT - NET	8,071,902	8,047,224
Regulatory assets:
Other regulatory assets	1,789,996	1,832,384
Deferred Fuel Cost Non Current	68,353	68,220
Other	20,675	14,028
Deferred Costs and Other Assets	1,879,024	1,914,632
TOTAL ASSETS	12,113,156	12,100,131
CURRENT LIABILITIES
Currently maturing long-term debt	90,000	485,000
Associated companies accounts payable	39,361	59,448
Accounts payable	190,966	208,591
Taxes Payable, Current	90,202	81,837
Interest accrued	41,582	22,745
Deferred fuel costs	0	53,065
Other	40,776	40,628
TOTAL	585,513	1,049,820
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,326,518	1,286,123
Accumulated deferred investment tax credits	30,200	30,500
Regulatory liability for income taxes - net	452,987	467,031
Other regulatory liabilities	662,312	686,872
Decommissioning and asset retirement cost liabilities	1,333,159	1,314,160
Loss Contingency Accrual	57,786	70,169
Pension and other postretirement liabilities	336,515	361,682
Long-term debt	3,868,751	3,482,507
Deferred Credits and Other Liabilities	90,209	75,098
TOTAL	8,158,437	7,774,142
Common Shareholders' Equity:
Members' Equity	3,369,206	3,276,169
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	3,369,206	3,276,169
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	12,113,156	12,100,131
Contract with Customer, Liability, Current	92,626	98,506
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	233	1,303
Temporary cash investments	601,583	726,717
Total cash and cash equivalents	601,816	728,020
Securitization recovery trust account	8,800	2,700
Accounts receivable:
Customer	326,475	317,905
Allowance for doubtful accounts	(46,655)	(45,693)
Associated companies	144,640	81,624
Other	39,401	41,760
Accrued unbilled revenues	186,001	178,840
Total accounts receivable	649,862	574,436
Deferred Fuel Cost	206,065	2,250
Fuel inventory - at average cost	49,486	50,680
Public Utilities, Inventory	433,841	437,933
Deferred nuclear refueling outage costs	75,916	48,407
Prepaid Expense and Other Assets, Current	41,100	36,813
TOTAL	2,058,086	1,878,539
Investments in and Advances to Affiliates, at Fair Value	1,390,587	1,390,587
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,879,332	1,794,042
Non-utility property - at cost (less accumulated depreciation)	335,730	323,110
Other	13,521	13,399
TOTAL	3,619,170	3,521,138
PROPERTY, PLANT, AND EQUIPMENT
Electric	25,960,969	25,619,789
Natural gas	268,865	262,744
Construction work in progress	526,575	667,281
Nuclear fuel	252,555	210,128
TOTAL PROPERTY, PLANT, AND EQUIPMENT	27,008,964	26,759,942
Less - accumulated depreciation and amortization	9,502,347	9,372,224
PROPERTY, PLANT, AND EQUIPMENT - NET	17,506,617	17,387,718
Regulatory assets:
Other regulatory assets	1,796,850	1,726,066
Deferred Fuel Cost Non Current	168,122	168,122
Other	32,212	23,924
Deferred Costs and Other Assets	1,997,184	1,918,112
TOTAL ASSETS	25,181,057	24,705,507
CURRENT LIABILITIES
Currently maturing long-term debt	200,000	240,000
Associated companies accounts payable	75,431	103,148
Accounts payable	685,493	1,450,008
Taxes Payable, Current	63,236	42,617
Interest accrued	83,086	92,249
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	31,138	31,138
Other	60,652	62,968
TOTAL	1,350,343	2,174,740
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,193,429	2,138,522
Accumulated deferred investment tax credits	106,135	107,317
Regulatory liability for income taxes - net	436,577	447,628
Other regulatory liabilities	951,847	918,293
Decommissioning and asset retirement cost liabilities	1,592,903	1,573,307
Loss Contingency Accrual	24,681	24,939
Pension and other postretirement liabilities	661,999	692,728
Long-term debt	9,859,885	8,787,451
Deferred Credits and Other Liabilities	379,367	382,894
TOTAL	16,206,823	15,073,079
Common Shareholders' Equity:
Accumulated other comprehensive loss	3,920	4,327
Members' Equity	7,619,971	7,453,361
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	7,623,891	7,457,688
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	25,181,057	24,705,507
Long-term Transition Bond, Noncurrent	10,344	10,278
Securitized Regulatory Transition Assets, Noncurrent	0	5,088
Contract with Customer, Liability, Current	151,307	152,612
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	11	11
Temporary cash investments	76,705	7
Total cash and cash equivalents	76,716	18
Accounts receivable:
Customer	104,649	105,732
Allowance for doubtful accounts	(16,771)	(19,527)
Associated companies	13,857	2,740
Other	13,596	11,821
Accrued unbilled revenues	50,075	59,514
Total accounts receivable	165,406	160,280
Deferred Fuel Cost	11,031	0
Fuel inventory - at average cost	15,381	17,117
Public Utilities, Inventory	61,336	59,542
Prepaid Expense and Other Assets, Current	3,792	4,876
TOTAL	333,662	241,833
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,539	4,543
Escrow accounts	64,637	64,635
TOTAL	69,176	69,178
PROPERTY, PLANT, AND EQUIPMENT
Electric	6,151,971	6,084,730
Construction work in progress	192,649	134,854
TOTAL PROPERTY, PLANT, AND EQUIPMENT	6,344,620	6,219,584
Less - accumulated depreciation and amortization	2,046,216	2,005,087
PROPERTY, PLANT, AND EQUIPMENT - NET	4,298,404	4,214,497
Regulatory assets:
Other regulatory assets	456,326	467,341
Other	19,886	14,413
Deferred Costs and Other Assets	476,212	481,754
TOTAL ASSETS	5,177,454	5,007,262
CURRENT LIABILITIES
Associated companies accounts payable	37,053	61,727
Accounts payable	144,652	117,629
Taxes Payable, Current	32,198	108,084
Interest accrued	25,127	20,889
Deferred fuel costs	0	14,691
Other	32,239	34,270
TOTAL	357,222	443,490
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	664,704	646,674
Accumulated deferred investment tax credits	11,080	9,062
Regulatory liability for income taxes - net	222,078	224,000
Other regulatory liabilities	36,897	15,828
Decommissioning and asset retirement cost liabilities	9,898	9,762
Loss Contingency Accrual	38,815	46,504
Pension and other postretirement liabilities	105,176	110,901
Long-term debt	1,981,429	1,780,577
Deferred Credits and Other Liabilities	51,449	47,730
TOTAL	3,121,526	2,891,038
Common Shareholders' Equity:
Members' Equity	1,698,706	1,672,734
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,698,706	1,672,734
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	5,177,454	5,007,262
Contract with Customer, Liability, Current	85,953	86,200
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	15,612	26
Total cash and cash equivalents	15,612	26
Securitization recovery trust account	6,779	3,364
Accounts receivable:
Customer	82,902	70,694
Allowance for doubtful accounts	(19,365)	(17,430)
Associated companies	1,331	2,381
Other	5,060	4,248
Accrued unbilled revenues	23,009	31,069
Total accounts receivable	92,937	90,962
Deferred Fuel Cost	7,016	2,130
Fuel inventory - at average cost	0	1,978
Public Utilities, Inventory	16,434	16,550
Prepaid Expense and Other Assets, Current	14,733	3,715
TOTAL	153,511	118,725
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	38,841	83,038
TOTAL	39,857	84,054
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,806,961	1,821,638
Natural gas	352,817	348,024
Construction work in progress	26,927	12,460
TOTAL PROPERTY, PLANT, AND EQUIPMENT	2,186,705	2,182,122
Less - accumulated depreciation and amortization	751,117	740,796
PROPERTY, PLANT, AND EQUIPMENT - NET	1,435,588	1,441,326
Regulatory assets:
Other regulatory assets	237,911	266,790
Deferred Fuel Cost Non Current	4,080	4,080
Other	29,864	23,931
Deferred Costs and Other Assets	271,855	294,801
TOTAL ASSETS	1,900,811	1,938,906
CURRENT LIABILITIES
Notes Payable, Related Parties, Current	1,618	1,618
Associated companies accounts payable	66,122	54,234
Accounts payable	40,944	60,766
Taxes Payable, Current	4,713	4,700
Interest accrued	4,892	8,095
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	3,327	3,296
Other	6,160	5,462
TOTAL	155,091	166,083
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	341,217	338,714
Accumulated deferred investment tax credits	16,081	16,095
Regulatory liability for income taxes - net	55,180	55,675
Decommissioning and asset retirement cost liabilities	3,833	3,768
Loss Contingency Accrual	49,218	89,898
Long-term debt	629,883	629,704
Notes Payable, Related Parties, Noncurrent	10,911	10,911
Deferred Credits and Other Liabilities	30,709	21,141
TOTAL	1,137,032	1,165,906
Common Shareholders' Equity:
Members' Equity	608,688	606,917
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	608,688	606,917
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,900,811	1,938,906
Long-term Transition Bond, Noncurrent	41,352	41,291
Securitized Regulatory Transition Assets, Noncurrent	32,859	35,559
Contract with Customer, Liability, Current	27,315	27,912
Entergy Texas [Member]
Cash and cash equivalents:
Cash	25	26
Temporary cash investments	0	248,570
Total cash and cash equivalents	25	248,596
Securitization recovery trust account	28,072	36,233
Accounts receivable:
Customer	108,152	103,221
Allowance for doubtful accounts	(15,058)	(16,810)
Associated companies	14,385	18,892
Other	14,995	11,780
Accrued unbilled revenues	62,845	56,411
Total accounts receivable	185,319	173,494
Fuel inventory - at average cost	50,022	53,531
Public Utilities, Inventory	60,011	56,227
Prepaid Expense and Other Assets, Current	12,493	20,165
TOTAL	335,942	588,246
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	336	349
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	17,552	19,889
TOTAL	18,264	20,614
PROPERTY, PLANT, AND EQUIPMENT
Electric	6,771,662	6,007,687
Construction work in progress	178,917	879,908
TOTAL PROPERTY, PLANT, AND EQUIPMENT	6,950,579	6,887,595
Less - accumulated depreciation and amortization	1,898,407	1,864,494
PROPERTY, PLANT, AND EQUIPMENT - NET	5,052,172	5,023,101
Regulatory assets:
Other regulatory assets	484,229	524,713
Other	78,654	70,397
Deferred Costs and Other Assets	562,883	595,110
TOTAL ASSETS	5,969,261	6,227,071
CURRENT LIABILITIES
Currently maturing long-term debt	200,000	200,000
Associated companies accounts payable	81,613	55,944
Accounts payable	139,190	350,947
Taxes Payable, Current	47,315	52,438
Interest accrued	9,867	20,856
Deferred fuel costs	22,386	85,356
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	30,591	29,249
Other	12,377	12,370
TOTAL	577,170	843,442
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	635,212	639,422
Accumulated deferred investment tax credits	9,788	9,942
Regulatory liability for income taxes - net	164,680	175,594
Other regulatory liabilities	28,220	32,297
Decommissioning and asset retirement cost liabilities	8,175	8,063
Loss Contingency Accrual	8,351	8,382
Long-term debt	2,265,827	2,293,708
Deferred Credits and Other Liabilities	64,672	58,643
TOTAL	$ 3,184,925	$ 3,226,051
Common Stock, Shares, Outstanding	46,525,000	46,525,000
Common Stock, Shares, Issued	46,525,000	46,525,000
Common Shareholders' Equity:
Common Stock, Value, Issued	$ 49,452	$ 49,452
Additional Paid in Capital, Common Stock	955,162	955,162
TOTAL	2,172,166	2,122,578
Stockholders' Equity Attributable to Noncontrolling Interest	35,000	35,000
Retained Earnings (Accumulated Deficit)	1,167,552	1,117,964
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,207,166	2,157,578
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	5,969,261	6,227,071
Long-term Transition Bond, Noncurrent	95,185	123,066
Securitized Regulatory Transition Assets, Noncurrent	60,618	78,590
Contract with Customer, Liability, Current	$ 33,831	$ 36,282
Common Stock, Shares Authorized	200,000,000	200,000,000
System Energy [Member]
Cash and cash equivalents:
Cash	$ 78	$ 26,086
Temporary cash investments	132,149	216,383
Total cash and cash equivalents	132,227	242,469
Accounts receivable:
Associated companies	59,422	57,743
Other	4,294	2,550
Total accounts receivable	63,716	60,293
Public Utilities, Inventory	126,444	123,006
Deferred nuclear refueling outage costs	27,932	34,459
Prepaid Expense and Other Assets, Current	7,605	6,864
TOTAL	357,924	467,091
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,249,846	1,215,868
TOTAL	1,249,846	1,215,868
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,310,445	5,309,458
Construction work in progress	73,360	59,831
Nuclear fuel	150,948	175,005
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,534,753	5,544,294
Less - accumulated depreciation and amortization	3,381,583	3,355,367
PROPERTY, PLANT, AND EQUIPMENT - NET	2,153,170	2,188,927
Regulatory assets:
Other regulatory assets	518,040	538,963
Other	2,441	3,119
Deferred Costs and Other Assets	520,481	542,082
TOTAL ASSETS	4,281,421	4,413,968
CURRENT LIABILITIES
Currently maturing long-term debt	19	100,015
Associated companies accounts payable	4,644	15,309
Accounts payable	36,849	41,313
Taxes Payable, Current	49,613	82,977
Interest accrued	11,634	12,722
Other	4,247	4,248
TOTAL	107,006	256,584
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	340,689	359,835
Accumulated deferred investment tax credits	43,963	38,902
Regulatory liability for income taxes - net	134,350	151,829
Other regulatory liabilities	670,284	665,396
Decommissioning and asset retirement cost liabilities	978,439	968,910
Pension and other postretirement liabilities	117,988	125,412
Long-term debt	768,950	705,259
Deferred Credits and Other Liabilities	36,342	61,295
TOTAL	$ 3,091,005	$ 3,076,838
Common Stock, Shares, Outstanding	789,350	789,350
Common Stock, Shares, Issued	789,350	789,350
Common Shareholders' Equity:
Common Stock, Value, Issued	$ 951,850	$ 951,850
Retained Earnings (Accumulated Deficit)	131,560	128,696
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,083,410	1,080,546
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 4,281,421	$ 4,413,968
Common Stock, Shares Authorized	1,000,000	1,000,000

XML

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Net income	$ 339,145	$ 123,294
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	(29,580)	(21,710)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	22,967	53,899
Net unrealized investment gains	(44,687)	15,744
Other comprehensive income (loss)	(51,300)	47,933
Total comprehensive income	287,845	171,227
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,580	4,580
Comprehensive Income Attributable to Entergy Corporation	283,265	166,647
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	6,314	15,076
Other Comprehensive Income (Loss), Securities, Available-for-sale, Tax	(25,581)	8,743
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	7,869	5,777
Entergy Louisiana [Member]
Net income	166,626	189,396
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	(407)	9,467
Other comprehensive income (loss)	(407)	9,467
Total comprehensive income	166,219	198,863
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	(144)	3,340
Entergy Arkansas [Member]
Net income	$ 93,037	$ 44,595

XML

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 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	$ 10,258,675	$ 35,000	$ 6,564,436	$ 9,257,609	$ (446,920)	$ 2,700	$ (5,154,150)	$ 1,799,407	$ 35,000	$ 780,182	$ 934,773	$ 49,452	$ 1,542,151	$ 3,125,937	$ 6,397,118	$ 6,392,556	$ 4,562	$ 497,579	$ 712,068	$ 110,218	$ 601,850
Consolidated net income	123,294	4,580	0	118,714	0	0	0	32,707	0	0	32,707	0	22,526	44,595	189,396	189,396	0	11,186	28,513	28,513	0
Proceeds from Contributions from Parent								175,000	0	175,000	0	0
Dividends, Common Stock, Cash	(185,763)	0	0	(185,763)	0	0	0						(2,500)		(11,500)	(11,500)	0		(13,653)	(13,653)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,580)	(4,580)	0	0	0	0	0
Other comprehensive income (loss)	47,933	0	0	0	47,933	0	0								9,467	0	9,467
Common stock issuances related to stock plans	(19,827)	0	53,753	0	0	0	(73,580)
Other															(10)	(10)	0
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,580							470
Dividends, Preferred Stock, Cash	4,100							470	0	0	470	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	10,258,967	35,000	6,510,683	9,190,141	(398,987)	2,700	(5,080,570)	2,006,644	35,000	955,182	967,010	49,452	1,562,177	3,170,532	6,584,471	6,570,442	14,029	508,765	726,928	125,078	601,850
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	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	166,626	166,626	0	1,771	23,864	23,864	0
Proceeds from Contributions from Parent								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
Dividends, Preferred Stock, Cash	4,100							470	0	0	470	0
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	$ 7,623,891	$ 7,619,971	$ 3,920	$ 608,688	$ 1,083,410	$ 131,560	$ 951,850

XML

Commitments and Contingencies

3 Months Ended

Mar. 31, 2021

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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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 commissions, 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 January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously capitalized, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously capitalized, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

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.

XML

Rate And Regulatory Matters

3 Months Ended

Mar. 31, 2021

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over 5 months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC jurisdictional utilities.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

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)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021 Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of March 31, 2021, Entergy Arkansas recorded a regulatory asset of $11.4 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. Settlement discussions are in progress.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. Entergy Louisiana and the LPSC staff filed a joint motion asking the LPSC to consider and approve the uncontested settlement at the May 2021 LPSC meeting. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

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. The suspension of late fees and disconnects for non-payment was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. 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, 2021, Entergy Louisiana recorded a regulatory asset of $47.8 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% 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 $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. A final order is expected in the second quarter 2021, with the resulting final rates, including amounts above the 2% cap of 2020 retail revenues, effective July 2021.

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. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Mississippi recorded a regulatory asset of $16.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding, currently being held in escrow, and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of March 31, 2021 the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021. As of March 31, 2021, Entergy New Orleans recorded a regulatory asset of $14.8 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 October 2020, 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 $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s currently effective

DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 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. This case has been remanded to the PUCT for consideration of a final order at a future open meeting.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s currently effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting.

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. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of March 31, 2021, Entergy Texas recorded a regulatory asset of $10.7 million for costs associated with the COVID-19 pandemic.

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 with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the ALJ issued an order unabating the proceeding to consider Entergy Texas’s updated application and establishing a procedural schedule that will result in administrative approval of Entergy Texas’s application in June 2021 if it is unopposed by parties to the proceeding.

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 is expected to close in June 2021. The initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. Once Entergy Texas has acquired the Hardin County Peaking Facility, its investment in the facility will be reflected in an updated filing to Entergy Texas’s application, which will be made within 60 days of the acquisition’s closing.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. 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 these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and the parties await further instructions from the court.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. 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 $59 million, which includes interest through March 31, 2021, and the estimated resulting annual rate reduction would be approximately $46 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 $36 million, including interest, as of March 31, 2021.

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 are due in May 2021. 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, 2021, is approximately $422 million, plus interest, which is approximately $115 million through March 31, 2021. 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, 2021.

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.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021, the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

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 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, and the first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other

respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

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

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 October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

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 incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

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. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.05 billion, including approximately $1.74 billion in capital costs and approximately $310 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.10 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow

account to the previously authorized amount of $290 million is appropriate. Entergy Louisiana intends to supplement this application with a request regarding the financing and recovery of the recoverable storm restoration costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric facilities damaged by Hurricane Zeta are currently estimated to be approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. Entergy New Orleans expects to initiate its storm cost recovery proceeding in May 2021.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

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 April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. Entergy Texas expects to initiate a proceeding later in 2021 to securitize the costs approved by the PUCT.

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Equity

3 Months Ended

Mar. 31, 2021

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,
	2021			2020
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$334.6	200.5	$1.67	$118.7	199.8	$0.59
Average dilutive effect of:
Stock options		0.4	(0.01)		0.7	—
Other equity plans		0.2	—		0.4	—
Diluted earnings per share	$334.6	201.1	$1.66	$118.7	200.9	$0.59

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.0 million for the three months ended March 31, 2021 and approximately 0.5 million for the three months ended March 31, 2020.

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 $0.95 for the three months ended March 31, 2021 and $0.93 for the three months ended March 31, 2020.

Treasury Stock

During the three months ended March 31, 2021, Entergy Corporation issued 388,330 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, 2021.

Retained Earnings

On April 12, 2021, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95 per share, payable on June 1, 2021, to holders of record as of May 6, 2021.

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, 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 for the three months ended March 31, 2020 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, 2020	$84,206	($557,072)	$25,946	($446,920)
Other comprehensive income (loss) before reclassifications	52,846	34,349	17,713	104,908
Amounts reclassified from accumulated other comprehensive income (loss)	(74,556)	19,550	(1,969)	(56,975)
Net other comprehensive income (loss) for the period	(21,710)	53,899	15,744	47,933
Ending balance, March 31, 2020	$62,496	($503,173)	$41,690	($398,987)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2021 and 2020:

	Pension and Other Postretirement Liabilities
	2021	2020
	(In Thousands)
Beginning balance, January 1,	$4,327	$4,562
Other comprehensive income (loss) before reclassifications	—	10,050
Amounts reclassified from accumulated other comprehensive income (loss)	(407)	(583)
Net other comprehensive income (loss) for the period	(407)	9,467
Ending balance, March 31,	$3,920	$14,029

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$39,367	$94,423	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	39,319	94,375
Income taxes	(8,257)	(19,819)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	$31,062	$74,556
Pension and other postretirement liabilities
Amortization of prior-service credit	$5,248	$3,719	(a)
Amortization of loss	(34,529)	(27,318)	(a)
Total amortization	(29,281)	(23,599)
Income taxes	6,314	4,049	Income taxes
Total amortization (net of tax)	($22,967)	($19,550)
Net unrealized investment gain (loss)
Realized gain (loss)	($972)	$3,116	Interest and investment income
Income taxes	358	(1,147)	Income taxes
Total realized investment gain (loss) (net of tax)	($614)	$1,969
Total reclassifications for the period (net of tax)	$7,481	$56,975

(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, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,230	$1,089	(a)
Amortization of loss	(679)	(301)	(a)
Total amortization	551	788
Income taxes	(144)	(205)	Income taxes
Total amortization (net of tax)	407	583
Total reclassifications for the period (net of tax)	$407	$583

(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,
	2021			2020
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$334.6	200.5	$1.67	$118.7	199.8	$0.59
Average dilutive effect of:
Stock options		0.4	(0.01)		0.7	—
Other equity plans		0.2	—		0.4	—
Diluted earnings per share	$334.6	201.1	$1.66	$118.7	200.9	$0.59

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.0 million for the three months ended March 31, 2021 and approximately 0.5 million for the three months ended March 31, 2020.

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 $0.95 for the three months ended March 31, 2021 and $0.93 for the three months ended March 31, 2020.

Treasury Stock

During the three months ended March 31, 2021, Entergy Corporation issued 388,330 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, 2021.

Retained Earnings

On April 12, 2021, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95 per share, payable on June 1, 2021, to holders of record as of May 6, 2021.

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, 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 for the three months ended March 31, 2020 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, 2020	$84,206	($557,072)	$25,946	($446,920)
Other comprehensive income (loss) before reclassifications	52,846	34,349	17,713	104,908
Amounts reclassified from accumulated other comprehensive income (loss)	(74,556)	19,550	(1,969)	(56,975)
Net other comprehensive income (loss) for the period	(21,710)	53,899	15,744	47,933
Ending balance, March 31, 2020	$62,496	($503,173)	$41,690	($398,987)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2021 and 2020:

	Pension and Other Postretirement Liabilities
	2021	2020
	(In Thousands)
Beginning balance, January 1,	$4,327	$4,562
Other comprehensive income (loss) before reclassifications	—	10,050
Amounts reclassified from accumulated other comprehensive income (loss)	(407)	(583)
Net other comprehensive income (loss) for the period	(407)	9,467
Ending balance, March 31,	$3,920	$14,029

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$39,367	$94,423	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	39,319	94,375
Income taxes	(8,257)	(19,819)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	$31,062	$74,556
Pension and other postretirement liabilities
Amortization of prior-service credit	$5,248	$3,719	(a)
Amortization of loss	(34,529)	(27,318)	(a)
Total amortization	(29,281)	(23,599)
Income taxes	6,314	4,049	Income taxes
Total amortization (net of tax)	($22,967)	($19,550)
Net unrealized investment gain (loss)
Realized gain (loss)	($972)	$3,116	Interest and investment income
Income taxes	358	(1,147)	Income taxes
Total realized investment gain (loss) (net of tax)	($614)	$1,969
Total reclassifications for the period (net of tax)	$7,481	$56,975

(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, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,230	$1,089	(a)
Amortization of loss	(679)	(301)	(a)
Total amortization	551	788
Income taxes	(144)	(205)	Income taxes
Total amortization (net of tax)	407	583
Total reclassifications for the period (net of tax)	$407	$583

(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

3 Months Ended

Mar. 31, 2021

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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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 September 2024.  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, 2021 was 1.63% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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 Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility 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, 2021, Entergy Corporation had approximately $1,028 million of commercial paper outstanding.  The weighted-average interest rate for the three months ended March 31, 2021 was 0.34%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
System Energy	$200	$—

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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 0.125% 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.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of March 31, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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 have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay on or prior to maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.480 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.680 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were held in trust as of April 1, 2021 and are expected to be applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

Fair Value

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

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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

3 Months Ended

Mar. 31, 2021

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 508,704 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2021 with a fair value of $12.27 per option.  As of March 31, 2021, there were options on 2,890,582 shares of common stock outstanding with a weighted-average exercise price of $90.75.  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, 2021.  The aggregate intrinsic value of the stock options outstanding as of March 31, 2021 was $41.6 million.

The following table includes financial information for outstanding stock options for the three months ended March 31, 2021 and 2020:

	2021	2020
	(In Millions)
Compensation expense included in Entergy’s net income	$1.0	$1.0
Tax benefit recognized in Entergy’s 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 2021 the Board approved and Entergy granted 392,382 restricted stock awards and 203,983 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on January 28, 2021 and were valued at $95.87 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, Entergy Corporation is replacing the cumulative adjusted earnings per share metric with a credit measure – adjusted funds from operations/debt ratio for the 2021-2023 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 28, 2021 and eighty percent were valued at $110.74 per share based on various factors, primarily market conditions; and twenty percent were valued at $95.87 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, 2021 and 2020:

	2021	2020
	(In Millions)
Compensation expense included in Entergy’s net income	$10.8	$9.4
Tax benefit recognized in Entergy’s net income	$2.7	$2.4
Compensation cost capitalized as part of fixed assets and materials and supplies	$4.0	$3.4

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Retirement And Other Postretirement Benefits

3 Months Ended

Mar. 31, 2021

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2021 and 2020, respectively.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

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.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of March 31, 2021, Entergy had contributed $152.2 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 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

XML

Business Segment Information

3 Months Ended

Mar. 31, 2021

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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and 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 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and 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 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and 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 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and 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 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and 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 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and 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 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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, 2021 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.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was 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 the remaining plants in the merchant nuclear fleet. These decisions and 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 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $40 million in 2021, of which $13 million has been incurred as of March 31, 2021, and a total of approximately $15 million in 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, 2021

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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow 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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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 other than those instruments held by the Entergy Wholesale Commodities business 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.

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow 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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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 other than those instruments held by the Entergy Wholesale Commodities business 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.

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow 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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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 other than those instruments held by the Entergy Wholesale Commodities business 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.

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow 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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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 other than those instruments held by the Entergy Wholesale Commodities business 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.

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow 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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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 other than those instruments held by the Entergy Wholesale Commodities business 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.

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow 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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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 other than those instruments held by the Entergy Wholesale Commodities business 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.

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas

contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

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 and interest rate swaps.  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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Entergy Wholesale Commodities is hedging the variability in future cash flows with derivatives for forecasted power transactions through April 30, 2021.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, of which approximately 12% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 5.8 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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 contain provisions that require 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 is an Entergy Corporation guarantee.  As of March 31, 2021, a derivative contract with one counterparty is in a liability position (approximately $1 million total). In addition to the corporate guarantee, $6 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $7 million in letters of credit

were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

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 had executed natural gas swaps and options as of March 31, 2021 was 3 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of March 31, 2021 was 7 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of March 31, 2021 was 41,296,000 MMBtu for Entergy, including 21,920,000 MMBtu for Entergy Louisiana and 19,376,000 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 2020, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2020 through May 31, 2021. 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, 2021 was 23,009 GWh for Entergy, including 5,765 GWh for Entergy Arkansas, 10,716 GWh for Entergy Louisiana, 2,576 GWh for Entergy Mississippi, 1,055 GWh for Entergy New Orleans, and 2,820 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, 2021 and December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of March 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

Based on market prices as of March 31, 2021, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $0.3 million, which are expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate 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 continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow 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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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 other than those instruments held by the Entergy Wholesale Commodities business 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.

The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs 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 are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are 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 are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are 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 are 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 confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is 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 review 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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

Entergy Louisiana

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

Entergy Mississippi

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

Entergy New Orleans

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

Entergy Texas

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

(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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

XML

Decommissioning Trust Funds

3 Months Ended

Mar. 31, 2021

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, Indian Point 1, Indian Point 2, Indian Point 3, 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. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized 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, 2021 on equity securities still held as of March 31, 2021 were $200 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$3,436	$102	$43
2020
Debt Securities	$2,617	$197	$3

The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of March 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $3,376 million as of March 31, 2021 and $2,423 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.59%, an average duration of approximately 5.98 years, and an average maturity of approximately 8.45 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,748	$43	$187	$3
More than 12 months	3	—	2	—
Total	$1,751	$43	$189	$3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($4)
1 year - 5 years	1,027	672
5 years - 10 years	1,257	852
10 years - 15 years	492	377
15 years - 20 years	128	144
20 years+	532	576
Total	$3,436	$2,617

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $524 million and $400 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $11 million and $14 million, respectively, and gross losses of $11 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2021 were $631 million for Indian Point 1, $760 million for Indian Point 2, $970 million for Indian Point 3, and $545 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$425.9	$13.2	$6.8
2020
Debt Securities	$447.9	$27.7	$0.3

The amortized cost of available-for-sale debt securities was $419.5 million as of March 31, 2021 and $420.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.42%, an average duration of approximately 6.40 years, and an average maturity of approximately 7.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $45.2 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$139.1	$6.8	$29.9	$0.3
More than 12 months	—	—	—	—
Total	$139.1	$6.8	$29.9	$0.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	84.7	113.1
5 years - 10 years	179.2	189.8
10 years - 15 years	100.8	81.4
15 years - 20 years	26.7	28.5
20 years+	34.5	35.1
Total	$425.9	$447.9

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $13.8 million and $48.6 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $0.8 million and $4.5 million, respectively, and gross losses of $0.1 million and $0.2 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$632.8	$31.2	$4.6
2020
Debt Securities	$632.2	$51.3	$0.5

The amortized cost of available-for-sale debt securities was $606.3 million as of March 31, 2021 and $581.4 million as of December 31, 2020.  As of March 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.25%, an average duration of approximately 6.59 years, and an average maturity of approximately 11.56 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $64.9 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$171.7	$4.6	$36.4	$0.5
More than 12 months	2.3	—	0.8	—
Total	$174.0	$4.6	$37.2	$0.5

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	89.3	117.0
5 years - 10 years	186.0	159.4
10 years - 15 years	113.7	101.2
15 years - 20 years	63.4	66.9
20 years+	180.4	187.7
Total	$632.8	$632.2

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $108.4 million and $67.4 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $3.3 million and $2.9 million, respectively, and gross losses of $3.2 million and $0.6 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$406.4	$14.3	$5.0
2020
Debt Securities	$427.7	$30.0	$0.8

The amortized cost of available-for-sale debt securities was $397 million as of March 31, 2021 and $398.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.36%, an average duration of approximately 6.31 years, and an average maturity of approximately 9.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $43.1 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, 2021 and December 31, 2020:

		March 31, 2021		December 31, 2020
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$157.5	$5.0	$28.9	$0.8
More than 12 months		—	—	—	—
Total		$157.5	$5.0	$28.9	$0.8

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($1.1)
1 year - 5 years	136.2	134.7
5 years - 10 years	120.4	141.5
10 years - 15 years	35.1	31.5
15 years - 20 years	4.5	5.3
20 years+	110.2	115.8
Total	$406.4	$427.7

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $74.1 million and $92 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $1.2 million and $1.7 million, respectively, and gross losses of $1.6 million and $0.2 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, 2021 and December 31, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $6.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021 and 2020.

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, Indian Point 1, Indian Point 2, Indian Point 3, 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. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized 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, 2021 on equity securities still held as of March 31, 2021 were $200 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$3,436	$102	$43
2020
Debt Securities	$2,617	$197	$3

The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of March 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $3,376 million as of March 31, 2021 and $2,423 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.59%, an average duration of approximately 5.98 years, and an average maturity of approximately 8.45 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,748	$43	$187	$3
More than 12 months	3	—	2	—
Total	$1,751	$43	$189	$3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($4)
1 year - 5 years	1,027	672
5 years - 10 years	1,257	852
10 years - 15 years	492	377
15 years - 20 years	128	144
20 years+	532	576
Total	$3,436	$2,617

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $524 million and $400 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $11 million and $14 million, respectively, and gross losses of $11 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2021 were $631 million for Indian Point 1, $760 million for Indian Point 2, $970 million for Indian Point 3, and $545 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$425.9	$13.2	$6.8
2020
Debt Securities	$447.9	$27.7	$0.3

The amortized cost of available-for-sale debt securities was $419.5 million as of March 31, 2021 and $420.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.42%, an average duration of approximately 6.40 years, and an average maturity of approximately 7.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $45.2 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$139.1	$6.8	$29.9	$0.3
More than 12 months	—	—	—	—
Total	$139.1	$6.8	$29.9	$0.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	84.7	113.1
5 years - 10 years	179.2	189.8
10 years - 15 years	100.8	81.4
15 years - 20 years	26.7	28.5
20 years+	34.5	35.1
Total	$425.9	$447.9

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $13.8 million and $48.6 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $0.8 million and $4.5 million, respectively, and gross losses of $0.1 million and $0.2 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$632.8	$31.2	$4.6
2020
Debt Securities	$632.2	$51.3	$0.5

The amortized cost of available-for-sale debt securities was $606.3 million as of March 31, 2021 and $581.4 million as of December 31, 2020.  As of March 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.25%, an average duration of approximately 6.59 years, and an average maturity of approximately 11.56 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $64.9 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$171.7	$4.6	$36.4	$0.5
More than 12 months	2.3	—	0.8	—
Total	$174.0	$4.6	$37.2	$0.5

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	89.3	117.0
5 years - 10 years	186.0	159.4
10 years - 15 years	113.7	101.2
15 years - 20 years	63.4	66.9
20 years+	180.4	187.7
Total	$632.8	$632.2

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $108.4 million and $67.4 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $3.3 million and $2.9 million, respectively, and gross losses of $3.2 million and $0.6 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$406.4	$14.3	$5.0
2020
Debt Securities	$427.7	$30.0	$0.8

The amortized cost of available-for-sale debt securities was $397 million as of March 31, 2021 and $398.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.36%, an average duration of approximately 6.31 years, and an average maturity of approximately 9.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $43.1 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, 2021 and December 31, 2020:

		March 31, 2021		December 31, 2020
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$157.5	$5.0	$28.9	$0.8
More than 12 months		—	—	—	—
Total		$157.5	$5.0	$28.9	$0.8

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($1.1)
1 year - 5 years	136.2	134.7
5 years - 10 years	120.4	141.5
10 years - 15 years	35.1	31.5
15 years - 20 years	4.5	5.3
20 years+	110.2	115.8
Total	$406.4	$427.7

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $74.1 million and $92 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $1.2 million and $1.7 million, respectively, and gross losses of $1.6 million and $0.2 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, 2021 and December 31, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $6.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021 and 2020.

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, Indian Point 1, Indian Point 2, Indian Point 3, 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. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized 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, 2021 on equity securities still held as of March 31, 2021 were $200 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$3,436	$102	$43
2020
Debt Securities	$2,617	$197	$3

The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of March 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $3,376 million as of March 31, 2021 and $2,423 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.59%, an average duration of approximately 5.98 years, and an average maturity of approximately 8.45 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,748	$43	$187	$3
More than 12 months	3	—	2	—
Total	$1,751	$43	$189	$3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($4)
1 year - 5 years	1,027	672
5 years - 10 years	1,257	852
10 years - 15 years	492	377
15 years - 20 years	128	144
20 years+	532	576
Total	$3,436	$2,617

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $524 million and $400 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $11 million and $14 million, respectively, and gross losses of $11 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2021 were $631 million for Indian Point 1, $760 million for Indian Point 2, $970 million for Indian Point 3, and $545 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$425.9	$13.2	$6.8
2020
Debt Securities	$447.9	$27.7	$0.3

The amortized cost of available-for-sale debt securities was $419.5 million as of March 31, 2021 and $420.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.42%, an average duration of approximately 6.40 years, and an average maturity of approximately 7.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $45.2 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$139.1	$6.8	$29.9	$0.3
More than 12 months	—	—	—	—
Total	$139.1	$6.8	$29.9	$0.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	84.7	113.1
5 years - 10 years	179.2	189.8
10 years - 15 years	100.8	81.4
15 years - 20 years	26.7	28.5
20 years+	34.5	35.1
Total	$425.9	$447.9

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $13.8 million and $48.6 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $0.8 million and $4.5 million, respectively, and gross losses of $0.1 million and $0.2 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$632.8	$31.2	$4.6
2020
Debt Securities	$632.2	$51.3	$0.5

The amortized cost of available-for-sale debt securities was $606.3 million as of March 31, 2021 and $581.4 million as of December 31, 2020.  As of March 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.25%, an average duration of approximately 6.59 years, and an average maturity of approximately 11.56 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $64.9 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$171.7	$4.6	$36.4	$0.5
More than 12 months	2.3	—	0.8	—
Total	$174.0	$4.6	$37.2	$0.5

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	89.3	117.0
5 years - 10 years	186.0	159.4
10 years - 15 years	113.7	101.2
15 years - 20 years	63.4	66.9
20 years+	180.4	187.7
Total	$632.8	$632.2

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $108.4 million and $67.4 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $3.3 million and $2.9 million, respectively, and gross losses of $3.2 million and $0.6 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$406.4	$14.3	$5.0
2020
Debt Securities	$427.7	$30.0	$0.8

The amortized cost of available-for-sale debt securities was $397 million as of March 31, 2021 and $398.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.36%, an average duration of approximately 6.31 years, and an average maturity of approximately 9.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $43.1 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, 2021 and December 31, 2020:

		March 31, 2021		December 31, 2020
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$157.5	$5.0	$28.9	$0.8
More than 12 months		—	—	—	—
Total		$157.5	$5.0	$28.9	$0.8

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($1.1)
1 year - 5 years	136.2	134.7
5 years - 10 years	120.4	141.5
10 years - 15 years	35.1	31.5
15 years - 20 years	4.5	5.3
20 years+	110.2	115.8
Total	$406.4	$427.7

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $74.1 million and $92 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $1.2 million and $1.7 million, respectively, and gross losses of $1.6 million and $0.2 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, 2021 and December 31, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $6.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021 and 2020.

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, Indian Point 1, Indian Point 2, Indian Point 3, 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. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized 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, 2021 on equity securities still held as of March 31, 2021 were $200 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$3,436	$102	$43
2020
Debt Securities	$2,617	$197	$3

The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of March 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $3,376 million as of March 31, 2021 and $2,423 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.59%, an average duration of approximately 5.98 years, and an average maturity of approximately 8.45 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,748	$43	$187	$3
More than 12 months	3	—	2	—
Total	$1,751	$43	$189	$3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($4)
1 year - 5 years	1,027	672
5 years - 10 years	1,257	852
10 years - 15 years	492	377
15 years - 20 years	128	144
20 years+	532	576
Total	$3,436	$2,617

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $524 million and $400 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $11 million and $14 million, respectively, and gross losses of $11 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2021 were $631 million for Indian Point 1, $760 million for Indian Point 2, $970 million for Indian Point 3, and $545 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$425.9	$13.2	$6.8
2020
Debt Securities	$447.9	$27.7	$0.3

The amortized cost of available-for-sale debt securities was $419.5 million as of March 31, 2021 and $420.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.42%, an average duration of approximately 6.40 years, and an average maturity of approximately 7.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $45.2 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$139.1	$6.8	$29.9	$0.3
More than 12 months	—	—	—	—
Total	$139.1	$6.8	$29.9	$0.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	84.7	113.1
5 years - 10 years	179.2	189.8
10 years - 15 years	100.8	81.4
15 years - 20 years	26.7	28.5
20 years+	34.5	35.1
Total	$425.9	$447.9

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $13.8 million and $48.6 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $0.8 million and $4.5 million, respectively, and gross losses of $0.1 million and $0.2 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$632.8	$31.2	$4.6
2020
Debt Securities	$632.2	$51.3	$0.5

The amortized cost of available-for-sale debt securities was $606.3 million as of March 31, 2021 and $581.4 million as of December 31, 2020.  As of March 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.25%, an average duration of approximately 6.59 years, and an average maturity of approximately 11.56 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $64.9 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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$171.7	$4.6	$36.4	$0.5
More than 12 months	2.3	—	0.8	—
Total	$174.0	$4.6	$37.2	$0.5

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	89.3	117.0
5 years - 10 years	186.0	159.4
10 years - 15 years	113.7	101.2
15 years - 20 years	63.4	66.9
20 years+	180.4	187.7
Total	$632.8	$632.2

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $108.4 million and $67.4 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $3.3 million and $2.9 million, respectively, and gross losses of $3.2 million and $0.6 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, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$406.4	$14.3	$5.0
2020
Debt Securities	$427.7	$30.0	$0.8

The amortized cost of available-for-sale debt securities was $397 million as of March 31, 2021 and $398.4 million as of December 31, 2020.  As of March 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.36%, an average duration of approximately 6.31 years, and an average maturity of approximately 9.62 years.

The unrealized gains/(losses) recognized during the three months ended March 31, 2021 on equity securities still held as of March 31, 2021 was $43.1 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, 2021 and December 31, 2020:

		March 31, 2021		December 31, 2020
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$157.5	$5.0	$28.9	$0.8
More than 12 months		—	—	—	—
Total		$157.5	$5.0	$28.9	$0.8

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of March 31, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($1.1)
1 year - 5 years	136.2	134.7
5 years - 10 years	120.4	141.5
10 years - 15 years	35.1	31.5
15 years - 20 years	4.5	5.3
20 years+	110.2	115.8
Total	$406.4	$427.7

During the three months ended March 31, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $74.1 million and $92 million, respectively.  During the three months ended March 31, 2021 and 2020, gross gains of $1.2 million and $1.7 million, respectively, and gross losses of $1.6 million and $0.2 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, 2021 and December 31, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $6.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the three months ended March 31, 2021 and 2020.

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Income Taxes

3 Months Ended

Mar. 31, 2021

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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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 commissions. 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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$18	$—

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Property, Plant, And Equipment

3 Months Ended

Mar. 31, 2021

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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 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, 2021 were $496.4 million for Entergy, $39.6 million for Entergy Arkansas, $330.4 million for Entergy Louisiana, $24.1 million for Entergy Mississippi, $4 million for Entergy New Orleans, $44.6 million for Entergy Texas, and $17.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy.

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Variable Interest Entities

3 Months Ended

Mar. 31, 2021

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

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 the three months ended March 31, 2021 and in the three months ended March 31, 2020.

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Revenue Recognition

3 Months Ended

Mar. 31, 2021

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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, 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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, 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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, 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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, 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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, 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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, 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, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

(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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

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Equity (Tables)

3 Months Ended

Mar. 31, 2021

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,
	2021			2020
	(In Millions, Except Per Share Data)
	Income	Shares	$/share	Income	Shares	$/share
Basic earnings per share
Net income attributable to Entergy Corporation	$334.6	200.5	$1.67	$118.7	199.8	$0.59
Average dilutive effect of:
Stock options		0.4	(0.01)		0.7	—
Other equity plans		0.2	—		0.4	—
Diluted earnings per share	$334.6	201.1	$1.66	$118.7	200.9	$0.59

Schedule of Accumulated Other Comprehensive Income (Loss)

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, 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 for the three months ended March 31, 2020 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, 2020	$84,206	($557,072)	$25,946	($446,920)
Other comprehensive income (loss) before reclassifications	52,846	34,349	17,713	104,908
Amounts reclassified from accumulated other comprehensive income (loss)	(74,556)	19,550	(1,969)	(56,975)
Net other comprehensive income (loss) for the period	(21,710)	53,899	15,744	47,933
Ending balance, March 31, 2020	$62,496	($503,173)	$41,690	($398,987)

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, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts	$39,367	$94,423	Competitive business operating revenues
Interest rate swaps	(48)	(48)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	39,319	94,375
Income taxes	(8,257)	(19,819)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)	$31,062	$74,556
Pension and other postretirement liabilities
Amortization of prior-service credit	$5,248	$3,719	(a)
Amortization of loss	(34,529)	(27,318)	(a)
Total amortization	(29,281)	(23,599)
Income taxes	6,314	4,049	Income taxes
Total amortization (net of tax)	($22,967)	($19,550)
Net unrealized investment gain (loss)
Realized gain (loss)	($972)	$3,116	Interest and investment income
Income taxes	358	(1,147)	Income taxes
Total realized investment gain (loss) (net of tax)	($614)	$1,969
Total reclassifications for the period (net of tax)	$7,481	$56,975

(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, 2021 and 2020:

	Pension and Other Postretirement Liabilities
	2021	2020
	(In Thousands)
Beginning balance, January 1,	$4,327	$4,562
Other comprehensive income (loss) before reclassifications	—	10,050
Amounts reclassified from accumulated other comprehensive income (loss)	(407)	(583)
Net other comprehensive income (loss) for the period	(407)	9,467
Ending balance, March 31,	$3,920	$14,029

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, 2021 and 2020 were as follows:

	Amounts reclassified from AOCI		Income Statement Location
	2021	2020
	(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit	$1,230	$1,089	(a)
Amortization of loss	(679)	(301)	(a)
Total amortization	551	788
Income taxes	(144)	(205)	Income taxes
Total amortization (net of tax)	407	583
Total reclassifications for the period (net of tax)	$407	$583

(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, 2021

Summary Of The Borrowings Outstanding And Capacity Available Under The Facility

Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2021.

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$55	$6	$3,439

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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
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, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
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, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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, 2021 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of March 31, 2021	Letters of Credit Outstanding as of March 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	$—	$—
Entergy Arkansas	September 2024	$150 million (c)	1.21%	$—	$—
Entergy Louisiana	September 2024	$350 million (c)	1.21%	$—	$—
Entergy Mississippi	April 2022	$37.5 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$35 million (d)	1.58%	$—	$—
Entergy Mississippi	April 2022	$10 million (d)	1.58%	$—	$—
Entergy New Orleans	November 2021	$25 million (c)	1.36%	$—	$—
Entergy Texas	September 2024	$150 million (c)	1.58%	$—	$1.3 million

(a)The interest rate is the estimated interest rate as of March 31, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the 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.

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, 2021:

Company	Amount of Uncommitted Facility	Letter of Credit Fee	MISO Letters of Credit Issued as of March 31, 2021 (a) (b)
Entergy Arkansas	$25 million	0.78%	$1 million
Entergy Louisiana	$125 million	0.78%	$12.8 million
Entergy Mississippi	$65 million	0.78%	$1 million
Entergy New Orleans	$15 million	1.00%	$2 million
Entergy Texas	$50 million	0.70%	$30.2 million

(a)As of March 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of March 31, 2021, in addition to the $1 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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
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, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$—
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$25
Entergy Texas	$200	$31
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 have commercial paper programs in place. Following is a summary as of March 31, 2021:

Company	Expiration Date	Amount of Facility	Weighted  Average Interest  Rate on  Borrowings (a)	Amount Outstanding as of March 31, 2021
		(Dollars in Millions)
Entergy Arkansas VIE	September 2022	$80	1.26%	$4.8
Entergy Louisiana River Bend VIE	September 2022	$105	1.24%	$70.5
Entergy Louisiana Waterford VIE	September 2022	$105	1.25%	$73.2
System Energy VIE	September 2022	$120	1.23%	$63.4

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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, 2021 as follows:

Company	Description	Amount
Entergy Arkansas VIE	3.65% Series L due July 2021	$90 million
Entergy Arkansas VIE	3.17% Series M due December 2023	$40 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, 2021 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$24,704,475	$25,716,967
Entergy Arkansas	$3,958,751	$4,126,514
Entergy Louisiana	$10,059,885	$10,681,713
Entergy Mississippi	$1,981,429	$2,084,891
Entergy New Orleans	$642,412	$584,475
Entergy Texas	$2,465,827	$2,545,973
System Energy	$768,969	$785,758

(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, 2020 were as follows:

	Book Value of Long-Term Debt	Fair Value of Long-Term Debt (a)
	(In Thousands)
Entergy	$22,369,776	$24,813,818
Entergy Arkansas	$3,967,507	$4,355,632
Entergy Louisiana	$9,027,451	$10,258,294
Entergy Mississippi	$1,780,577	$2,021,432
Entergy New Orleans	$642,233	$620,634
Entergy Texas	$2,493,708	$2,765,193
System Energy	$805,274	$840,540

(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 (Tables) - Entergy Corporation [Member]

3 Months Ended

Mar. 31, 2021

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, 2021 and 2020:

	2021	2020
	(In Millions)
Compensation expense included in Entergy’s net income	$1.0	$1.0
Tax benefit recognized in Entergy’s 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, 2021 and 2020:

	2021	2020
	(In Millions)
Compensation expense included in Entergy’s net income	$10.8	$9.4
Tax benefit recognized in Entergy’s net income	$2.7	$2.4
Compensation cost capitalized as part of fixed assets and materials and supplies	$4.0	$3.4

XML

Retirement And Other Postretirement Benefits (Tables)

3 Months Ended

Mar. 31, 2021

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$45,241	$40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of net loss	104,392	87,259
Net pension costs	$90,019	$84,872

Other Postretirement [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the first quarters of 2021 and 2020, included the following components:

	2021	2020
	(In Thousands)
Service cost - benefits earned during the period	$6,645	$5,801
Interest cost on accumulated postretirement benefit obligation (APBO)	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service credit	(8,267)	(5,922)
Amortization of net loss	713	468
Net other postretirement benefit income	($6,394)	($2,049)

Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

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 2021 and 2020:

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

2020	Qualified Pension Costs	Other Postretirement Costs	Non-Qualified Pension Costs	Total
	(In Thousands)
Entergy
Amortization of prior service (cost) credit	$—	$3,776	($57)	$3,719
Amortization of net gain (loss)	(26,462)	(25)	(831)	(27,318)
	($26,462)	$3,751	($888)	($23,599)
Entergy Louisiana
Amortization of prior service credit	$—	$1,089	$—	$1,089
Amortization of net gain (loss)	(499)	199	(1)	(301)
	($499)	$1,288	($1)	$788

Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Entergy Mississippi [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

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 cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

Entergy Texas [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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 the first quarters of 2021 and 2020:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$90	$44	$96	$8	$115
2020	$83	$37	$90	$8	$117

System Energy [Member] | Pension Plans Defined Benefit [Member]

Defined Benefit Plan Disclosure [Line Items]

Components Of Net Pension Cost

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2021 and 2020, included the following components:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy  Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$6,566	$8,794	$2,023	$663	$1,546	$1,965
Interest cost on projected benefit obligation	11,433	12,841	3,340	1,456	2,782	2,814
Expected return on assets	(19,622)	(22,402)	(5,757)	(2,627)	(5,486)	(4,663)
Amortization of net loss	16,897	16,627	4,748	2,005	3,265	4,279
Net pension cost	$15,274	$15,860	$4,354	$1,497	$2,107	$4,395

Expected Employer Contributions

Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021:

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Expected 2021 pension contributions	$66,649	$59,882	$13,715	$5,395	$6,955	$18,663
Pension contributions made through March 2021	$21,361	$29,159	$4,799	$2,629	$2,935	$6,675
Remaining estimated pension contributions to be made in 2021	$45,288	$30,723	$8,916	$2,766	$4,020	$11,988

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 2021 and 2020, included the following components:

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)

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Service cost - benefits earned during the period	$828	$1,423	$351	$105	$303	$294
Interest cost on APBO	1,217	1,723	422	227	582	307
Expected return on assets	(4,326)	—	(1,307)	(1,355)	(2,435)	(748)
Amortization of prior service credit	(661)	(1,089)	(321)	(76)	(550)	(219)
Amortization of net (gain) loss	55	(199)	29	(38)	212	20
Net other postretirement benefit cost (income)	($2,887)	$1,858	($826)	($1,137)	($1,888)	($346)

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Business Segment Information (Tables) - Entergy Corporation [Member]

3 Months Ended

Mar. 31, 2021

Segment Financial Information

Entergy’s segment financial information for the first quarters of 2021 and 2020 was as follows:

	Utility	Entergy Wholesale Commodities	All Other	Eliminations	Consolidated
	(In Thousands)
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 March 31, 2021	$56,086,185	$3,793,754	$867,301	($2,079,612)	$58,667,628
2020
Operating revenues	$2,094,629	$332,549	$11	($10)	$2,427,179
Income taxes	($52,949)	($30,540)	$12,295	$—	($71,194)
Consolidated net income (loss)	$323,849	($110,428)	($58,228)	($31,899)	$123,294
Total assets as of December 31, 2020	$55,940,153	$3,800,378	$552,632	($2,053,951)	$58,239,212

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

Restructuring and Related Costs [Table Text Block]

Total restructuring charges for the first quarters of 2021 and 2020 were comprised of the following:

	2021			2020
	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,	$145	$14	$159	$129	$14	$143
Restructuring costs accrued	13	—	13	21	—	21
Cash paid out	1	—	1	—	—	—
Balance as of March 31,	$157	$14	$171	$150	$14	$164

In addition, Entergy Wholesale Commodities incurred $3 million in the first quarter 2021 and $5 million in the first quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

XML

Risk Management And Fair Values (Tables)

3 Months Ended

Mar. 31, 2021

Fair Values Of Derivative Instruments

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2021 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 (current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$4	$—	$4	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$2	$—	$2	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Utility

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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 designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$39	($1)	$38	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$1	($1)	$—	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Natural gas swaps and options	Prepayments and other (current portion)	$1	$—	$1	Utility
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$9	$—	$9	Utility and Entergy Wholesale Commodities
Liabilities:
Natural gas swaps and options	Other current liabilities (current portion)	$6	$—	$6	Utility
Natural gas swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	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 $6 million posted as of March 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $7 million held as of March 31, 2021 and $1 million posted and $39 million held as of December 31, 2020

Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income

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 and 2020 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)
2021
Electricity swaps and options	$2	Competitive businesses operating revenues	$39
2020
Electricity swaps and options	$67	Competitive businesses operating revenues	$94

(a)Before taxes of $8 million and $20 million for the three months ended March 31, 2021 and 2020, respectively

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, 2021 and 2020 were as follows:

Instrument	Income Statement location		Amount of gain (loss) recorded in the income statement
			(In Millions)
2021
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	(a)	$7
Financial transmission rights	Purchased power expense	(b)	$128
Electricity swaps and options (c)	Competitive business operating revenues		($2)
2020
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	(a)	($7)
Financial transmission rights	Purchased power expense	(b)	$13
Electricity swaps and options (c)	Competitive business operating revenues		$—

(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.

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 were accounted for at fair value on a recurring basis as of March 31, 2021 and December 31, 2020.  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.

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,675	$—	$—	$1,675
Decommissioning trust funds (a):
Equity securities	807	—	—	807
Debt securities (b)	1,489	1,947	—	3,436
Common trusts (c)				3,102
Securitization recovery trust account	44	—	—	44
Escrow accounts	103	—	—	103
Gas hedge contracts	1	—	—	1
Financial transmission rights	—	—	4	4
	$4,119	$1,947	$4	$9,172
Liabilities:
Gas hedge contracts	$2	$1	$—	$3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,630	$—	$—	$1,630
Decommissioning trust funds (a):
Equity securities	1,533	—	—	1,533
Debt securities (b)	919	1,698	—	2,617
Common trusts (c)				3,103
Power contracts	—	—	38	38
Securitization recovery trust account	42	—	—	42
Escrow accounts	148	—	—	148
Gas hedge contracts	1	1	—	2
Financial transmission rights	—	—	9	9
	$4,273	$1,699	$47	$9,122
Liabilities:
Gas hedge contracts	$6	$1	$—	$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 values presented herein do not include the recognition of a credit loss valuation allowance of $6.4 million as of March 31, 2021 and $0.1 million as of December 31, 2020 on debt securities due to the adoption of ASU 2016-13. 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, 2021 and 2020:

	2021		2020
	Power Contracts	Financial transmission rights	Power Contracts	Financial transmission rights
	(In Millions)
Balance as of January 1,	$38	$9	$118	$10
Total gains (losses) for the period (a)
Included in earnings	(2)	4	(18)	—
Included in other comprehensive income	2	—	67	—
Included as a regulatory liability/asset	—	119	—	7
Settlements	(38)	(128)	(82)	(13)
Balance as of March 31,	$—	$4	$85	$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 and $1 million for the three months ended March 31, 2020.

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, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$123.7	$—	$—	$123.7
Decommissioning trust funds (a):
Equity securities	53.3	—	—	53.3
Debt securities	89.9	336.0	—	425.9
Common trusts (b)				831.9
Financial transmission rights	—	—	1.4	1.4
	$266.9	$336.0	$1.4	$1,436.2

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$168.0	$—	$—	$168.0
Decommissioning trust funds (a):
Equity securities	1.3	—	—	1.3
Debt securities	98.2	349.7	—	447.9
Common trusts (b)				824.7
Financial transmission rights	—	—	2.7	2.7
	$267.5	$349.7	$2.7	$1,444.6

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, 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$601.6	$—	$—	$601.6
Decommissioning trust funds (a):
Equity securities	68.8	—	—	68.8
Debt securities	218.9	413.9	—	632.8
Common trusts (b)				1,177.7
Securitization recovery trust account	8.8	—	—	8.8
Gas hedge contracts	1.0	0.4	—	1.4
Financial transmission rights	—	—	1.2	1.2
	$899.1	$414.3	$1.2	$2,492.3
Liabilities:
Gas hedge contracts	$—	$0.8	$—	$0.8

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9
Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

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, 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$76.7	$—	$—	$76.7
Escrow accounts	64.6	—	—	64.6
Financial transmission rights	—	—	0.3	0.3
	$141.3	$—	$0.3	$141.6
Liabilities:
Gas hedge contracts	$2.3	$—	$—	$2.3

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2
Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

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, 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$6.8	$—	$—	$6.8
Escrow accounts	38.8	—	—	38.8
Financial transmission rights	—	—	0.1	0.1
	$45.6	$—	$0.1	$45.7

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$3.4	$—	$—	$3.4
Escrow accounts	83.0	—	—	83.0
Financial transmission rights	—	—	0.1	0.1
	$86.4	$—	$0.1	$86.5
Liabilities:
Gas hedge contracts	$0.3	$—	$—	$0.3

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, 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

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, 2021 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	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets (non-current portion)	$0.4	$—	$0.4	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.5	($0.1)	$1.4	Entergy Arkansas
Financial transmission rights	Prepayments and other	$1.3	($0.1)	$1.2	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	$0.5	$—	$0.5	Entergy Texas
Liabilities:
Natural gas swaps and options	Other non-current liabilities	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps	Other current liabilities	$2.3	$—	$2.3	Entergy Mississippi

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 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	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana
Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas
Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	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, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.4 million for Entergy Arkansas, $0.2 million for Entergy Louisiana, $0.4 million for Entergy Mississippi, and $0.1 million for Entergy New Orleans. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 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, 2021 and 2020 were as follows:

Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
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 expense	$26.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$12.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$7.2	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$1.3	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$77.9	(b)	Entergy Texas
2020
Natural gas swaps and options	Fuel, fuel-related expenses, and gas purchased for resale	($1.3)	(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	($0.4)	(a)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$4.6	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$5.3	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	($0.1)	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$0.4	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$2.4	(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

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Securitization recovery trust account	$28.1	$—	$—	$28.1
Financial transmission rights	—	—	0.5	0.5
	$28.1	$—	$0.5	$28.6

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$248.6	$—	$—	$248.6
Securitization recovery trust account	36.2	—	—	36.2
Financial transmission rights	—	—	1.6	1.6
	$284.8	$—	$1.6	$286.4

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 (liabilities) 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

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, 2020.

	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1,	$3.3	$4.5	$0.8	$0.3	$0.9
Gains (losses) included as a regulatory liability/asset	2.4	2.7	(0.6)	0.1	1.8
Settlements	(4.6)	(5.3)	0.1	(0.4)	(2.4)
Balance as of March 31,	$1.1	$1.9	$0.3	$—	$0.3

System Energy [Member]

Assets and liabilities at fair value on a recurring basis

System Energy

2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$132.1	$—	$—	$132.1
Decommissioning trust funds (a):
Equity securities	60.6	—	—	60.6
Debt Securities	179.4	227.0	—	406.4
Common trusts (b)				782.8
	$372.1	$227.0	$—	$1,381.9

2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$216.4	$—	$—	$216.4
Decommissioning trust funds (a):
Equity securities	3.8	—	—	3.8
Debt securities	177.3	250.4	—	427.7
Common trusts (b)				784.4
	$397.5	$250.4	$—	$1,432.3

XML

Decommissioning Trust Funds (Tables)

3 Months Ended

Mar. 31, 2021

Securities Held

The available-for-sale securities held as of March 31, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$3,436	$102	$43
2020
Debt Securities	$2,617	$197	$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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$1,748	$43	$187	$3
More than 12 months	3	—	2	—
Total	$1,751	$43	$189	$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, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($4)
1 year - 5 years	1,027	672
5 years - 10 years	1,257	852
10 years - 15 years	492	377
15 years - 20 years	128	144
20 years+	532	576
Total	$3,436	$2,617

Entergy Arkansas [Member]

Securities Held

The available-for-sale securities held as of March 31, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$425.9	$13.2	$6.8
2020
Debt Securities	$447.9	$27.7	$0.3

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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$139.1	$6.8	$29.9	$0.3
More than 12 months	—	—	—	—
Total	$139.1	$6.8	$29.9	$0.3

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, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	84.7	113.1
5 years - 10 years	179.2	189.8
10 years - 15 years	100.8	81.4
15 years - 20 years	26.7	28.5
20 years+	34.5	35.1
Total	$425.9	$447.9

Entergy Louisiana [Member]

Securities Held

The available-for-sale securities held as of March 31, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$632.8	$31.2	$4.6
2020
Debt Securities	$632.2	$51.3	$0.5

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, 2021 and December 31, 2020:

	March 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$171.7	$4.6	$36.4	$0.5
More than 12 months	2.3	—	0.8	—
Total	$174.0	$4.6	$37.2	$0.5

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, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	89.3	117.0
5 years - 10 years	186.0	159.4
10 years - 15 years	113.7	101.2
15 years - 20 years	63.4	66.9
20 years+	180.4	187.7
Total	$632.8	$632.2

System Energy [Member]

Securities Held

The available-for-sale securities held as of March 31, 2021 and December 31, 2020 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$406.4	$14.3	$5.0
2020
Debt Securities	$427.7	$30.0	$0.8

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, 2021 and December 31, 2020:

		March 31, 2021		December 31, 2020
		Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months		$157.5	$5.0	$28.9	$0.8
More than 12 months		—	—	—	—
Total		$157.5	$5.0	$28.9	$0.8

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, 2021 and December 31, 2020 were as follows:

	2021	2020
	(In Millions)
Less than 1 year	$—	($1.1)
1 year - 5 years	136.2	134.7
5 years - 10 years	120.4	141.5
10 years - 15 years	35.1	31.5
15 years - 20 years	4.5	5.3
20 years+	110.2	115.8
Total	$406.4	$427.7

XML

Income Taxes Income Taxes (Tables)

3 Months Ended

Mar. 31, 2021

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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$18	$—

Entergy Mississippi [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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$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,
	2021	2020
	(In Millions)
Entergy	$41	$30
Entergy Arkansas	$8	$13
Entergy Louisiana	$8	$8
Entergy New Orleans	$—	$3
Entergy Texas	$7	$6
System Entergy	$18	$—

XML

Revenue Recognition Revenue Recognition (Tables)

3 Months Ended

Mar. 31, 2021

Disaggregation of Revenue [Table Text Block]

Entergy’s total revenues for the three months ended March 31, 2021 and 2020 were as follows:

	2021	2020
	(In Thousands)
Utility:
Residential	$966,855	$798,028
Commercial	572,676	538,940
Industrial	597,652	557,515
Governmental	56,798	52,582
Total billed retail	2,193,981	1,947,065
Sales for resale (a)	205,075	53,725
Other electric revenues (b)	80,261	50,166
Revenues from contracts with customers	2,479,317	2,050,956
Other revenues (c)	59,103	(318)
Total electric revenues	2,538,420	2,050,638
Natural gas	58,168	43,976
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)	232,113	216,002
Other revenues (c)	16,137	116,563
Total competitive businesses revenues	248,250	332,565
Total operating revenues	$2,844,838	$2,427,179

Allowance for Doubtful Accounts

The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

Entergy Arkansas [Member]

Disaggregation of Revenue [Table Text Block]

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

Allowance for Doubtful Accounts

The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

Entergy Louisiana [Member]

Disaggregation of Revenue [Table Text Block]

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

Allowance for Doubtful Accounts

The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

Entergy Mississippi [Member]

Disaggregation of Revenue [Table Text Block]

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

Allowance for Doubtful Accounts

The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

Entergy New Orleans [Member]

Disaggregation of Revenue [Table Text Block]

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

Allowance for Doubtful Accounts

The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

Entergy Texas [Member]

Disaggregation of Revenue [Table Text Block]

The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2021 and 2020 were as follows:

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

2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Residential	$219,688	$259,860	$127,102	$50,899	$140,480
Commercial	111,245	202,246	96,798	45,505	83,146
Industrial	101,088	322,342	36,390	7,347	90,348
Governmental	4,030	16,754	10,327	15,851	5,620
Total billed retail	436,051	801,202	270,617	119,602	319,594
Sales for resale (a)	41,140	78,530	14,422	10,170	8,629
Other electric revenues (b)	1,596	32,008	6,443	763	10,702
Revenues from contracts with customers	478,787	911,740	291,482	130,535	338,925
Other revenues (c)	3,125	801	2,440	(7,104)	411
Total electric revenues	481,912	912,541	293,922	123,431	339,336
Natural gas	—	18,106	—	25,871	—
Total operating revenues	$481,912	$930,647	$293,922	$149,302	$339,336

Allowance for Doubtful Accounts

The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the three months ended March 31, 2021 and 2020.

	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	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of December 31, 2019	$7.4	$1.2	$1.9	$0.6	$3.2	$0.5
Provisions	6.6	1.2	3.0	0.9	0.8	0.7
Write-offs	(8.4)	(1.8)	(3.5)	(1.2)	(0.8)	(1.1)
Recoveries	2.9	0.9	1.1	0.3	0.2	0.5
Balance as of March 31, 2020	$8.5	$1.5	$2.5	$0.6	$3.4	$0.6

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Commitments and Contingencies Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Jan. 31, 2021	Mar. 31, 2021	Mar. 31, 2020
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		$ 15,735	$ 62,162
Entergy Arkansas [Member]
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		$ 0	$ 55,001
Entergy Wholesale Commodities [Member] | Palisades [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party	$ 23,100
Damages awarded for previously recorded operation and maintenance	7,100
Damages awarded for previously capitalized costs	15,700
Damages awarded for previously recorded taxes other than income taxes	300
Reduction of previously recorded deprecation expense	$ 9,100

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Rate And Regulatory Matters (Narrative) (Details) - USD ($)	1 Months Ended							3 Months Ended		8 Months Ended			12 Months Ended			14 Months Ended	24 Months Ended		36 Months Ended
	Apr. 30, 2021	Mar. 31, 2021	Feb. 28, 2021	Dec. 31, 2020	Nov. 30, 2020	Oct. 31, 2020	May 31, 2019	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2021	Feb. 28, 2021	Aug. 31, 2020	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2020	Aug. 31, 2020	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2022	Jun. 30, 2020	Apr. 30, 2020
Regulatory Assets [Line Items]
Impairment of Long-Lived Assets Held-for-use								$ 3,278,000	$ 4,962,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		$ 1,311,997,000		$ 2,012,030,000				1,311,997,000						$ 1,311,997,000	$ 2,012,030,000
Proceeds from the issuance of long-term debt								3,676,242,000	3,195,345,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount							$ 109,500,000								63,000,000
Regulatory asset related to costs associated with COVID-19 pandemic		47,800,000						47,800,000						47,800,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		526,575,000		667,281,000				526,575,000						526,575,000	667,281,000
Proceeds from the issuance of long-term debt								1,399,245,000	1,221,900,000
Amount transfer from restricted escrow account as storm damage reserve					$ 257,000,000
Estimated remaining costs for completion of J. Wayne Leonard Power Station								3,100,000
Entergy Louisiana [Member] | Mortgage Bonds Zero Point Six Two Percent Series Due November 2023
Regulatory Assets [Line Items]
Proceeds from the issuance of long-term debt					$ 1,100,000,000
Debt instrument, interest rate, stated percentage					0.62%
Entergy Louisiana [Member] | Winter Storm Uri
Regulatory Assets [Line Items]
Fuel Costs			$ 166,000,000
Entergy Louisiana [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Distribution recovery mechanism - amount per year																			$ 225,000,000
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent																			21.00%
Formula rate plan revenue increase limit - exclusive of riders																	$ 70,000,000
Deferral of expenditures on vegetation management																		$ 7,000,000
Authorized return on common equity																			9.50%
Storm Reserve Escrow Account	$ 290,000,000
Entergy Louisiana [Member] | Subsequent Event [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri [Domain]
Regulatory Assets [Line Items]
Total Restoration Costs For Repair and Replacement of Electrical System	2,050,000,000.00
Non-capital storm costs	310,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent	1,740,000,000
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs	2,100,000,000
Entergy Louisiana [Member] | Subsequent Event [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Authorized return on common equity																			9.00%
Entergy Louisiana [Member] | Subsequent Event [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Authorized return on common equity																			10.00%
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		95,400,000
Rate Increase Included in Formula Rate Plan		44,300,000
Regulatory asset related to costs associated with COVID-19 pandemic		16,300,000						16,300,000						16,300,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		$ 192,649,000		134,854,000				192,649,000						192,649,000	134,854,000
Proceeds from the issuance of long-term debt								200,573,000	0
Public Utilities, Requested Return on Equity, Percentage		6.69%
Cap on 2020 retail revenues		2.00%
Demand side management costs		$ 3,900,000
Interim increase in formula rate plan revenues		16,800,000
Interim rate adjustment		1,700,000
Total interim rate adjustments		18,500,000
Interim increase in formula rate plan revenues due to adjustments		22,100,000
Formula rate plan revenue increase including demand side management costs		$ 48,200,000
Entergy Mississippi [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage		4.00%
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
public utilities proposed customer credits											$ 100
Regulatory asset related to costs associated with COVID-19 pandemic		$ 14,800,000						14,800,000						14,800,000
Opportunity Sales Refund to be Redirected to Cares Program																				$ 7,000,000
Non-Securitized Storm Reserves Reallocated to Cares Program																				$ 15,000,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		26,927,000		12,460,000				26,927,000						26,927,000	12,460,000
Credits to customer bills resulting from City Council Cares Program		4,300,000						4,300,000						4,300,000
Proceeds from the issuance of long-term debt								0	139,116,000
Storm Reserve Escrow Account		38,841,000		83,038,000				38,841,000						38,841,000	83,038,000
Withdrawal from storm reserves		44,000,000
Entergy New Orleans [Member] | Maximum [Member]
Regulatory Assets [Line Items]
public utilities proposed customer credits											$ 400
Entergy New Orleans [Member] | Subsequent Event [Member] | Hurricane Zeta [Domain]
Regulatory Assets [Line Items]
Total Restoration Costs For Repair and Replacement of Electrical System	36,000,000
Non-capital storm costs	8,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent	28,000,000
Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory asset related to costs associated with COVID-19 pandemic		10,700,000						10,700,000						10,700,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		178,917,000		879,908,000				178,917,000						178,917,000	879,908,000
Proceeds from the issuance of long-term debt								0	194,631,000
Entergy Texas [Member] | Hurricane Laura [Member]
Regulatory Assets [Line Items]
Interim fuel refund for cumulative over-recovery			$ 75,000,000
Entergy Texas [Member] | Subsequent Event [Member] | Hurricanes Laura and Delta and Winter Storm Uri
Regulatory Assets [Line Items]
Total Restoration Costs For Repair and Replacement of Electrical System	250,000,000
Non-capital storm costs	50,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent	$ 200,000,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Energy Cost Recovery Rider Rate Per kWh														0.01052
Regulatory asset related to costs associated with COVID-19 pandemic		11,400,000						11,400,000						11,400,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		$ 288,269,000		234,213,000				288,269,000						288,269,000	234,213,000
Proceeds from the issuance of long-term debt								604,760,000	264,505,000
Provision for rate refund				43,500,000											43,500,000
Public Utilities, Requested Return on Equity, Percentage		9.75%
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Energy Cost Recovery Rider Rate Per kWh													$ 0.00959
Net change in required FRP rider revenue										$ 39,800,000
Public Utilities, Requested Return on Equity, Percentage	9.65%
System Energy [Member]
Regulatory Assets [Line Items]
Refund of Lease Payments																					$ 17,200,000
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		115,000,000						115,000,000						115,000,000
Refund related to depreciation expense adjustments		19,000,000						19,000,000						19,000,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		$ 73,360,000		59,831,000				73,360,000						73,360,000	$ 59,831,000
Proceeds from the issuance of long-term debt								189,244,000	$ 243,559,000
Authorized return on common equity		10.94%
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal		9.32%
Percent Equity in Proposed Common Equity Ratio		48.15%
Estimated refund related to FERC proceeding		$ 59,000,000						59,000,000						59,000,000
Estimated annual rate reduction		46,000,000						46,000,000						46,000,000
Provision related to FERC proceeding		36,000,000						$ 36,000,000						$ 36,000,000
One-time accumulated deferred income tax credit				25,200,000
Refund related to replacement energy costs		360,000,000
Pre-authorization of capital improvement projects		$ 125,000,000
Sale Leaseback Transaction, Net Book Value																					$ 70,000,000
Grand Gulf [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage								11.50%
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount						$ 26,300,000
Revenue increase resulting from incremental revenue												$ 6,800,000
Transmission Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount						51,000,000
Revenue increase resulting from incremental revenue																$ 31,600,000
Generation Cost Recovery Rider | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				$ 86,000,000		$ 91,000,000

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Equity (Narrative) (Details) - $ / shares		3 Months Ended
	Apr. 12, 2021	Mar. 31, 2021	Mar. 31, 2020
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation		1,000,000.0	500,000
Shares, Issued		388,330
Common stock dividend (in dollars per share)		$ 0.95	$ 0.93
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 0.95

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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, 2021	Mar. 31, 2020
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	400,000	700,000
Stock options $/share	$ (0.01)	$ 0
Restricted stock, Shares	200,000	400,000
Restricted stock $/share	$ 0	$ 0
Basic earnings per share
Net Income (Loss) Available to Common Stockholders, Basic	$ 334,565	$ 118,714
Net Income (Loss) Available to Common Stockholders, Diluted	$ 334,600	$ 118,700
Net Income Attributable to Entergy Corporation, Shares	200,525,549	199,790,016
Net Income Attributable to Entergy Corporation, $/share	$ 1.67	$ 0.59
Diluted earnings per share, Shares	201,059,665	200,901,349
Diluted earnings per share $/share	$ 1.66	$ 0.59

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Equity (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	$ (500,507)	$ (398,987)	$ (449,207)	$ (446,920)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(43,819)	104,908
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(7,481)	(56,975)
Other comprehensive income (loss)	(51,300)	47,933
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	11,963	41,690	56,650	25,946
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(45,301)	17,713
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	614	(1,969)
Other comprehensive income (loss)	(44,687)	15,744
Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	(51,300)	47,933
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(511,609)	(503,173)	(534,576)	(557,072)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	34,349
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	22,967	19,550
Other comprehensive income (loss)	22,967	53,899
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(861)	62,496	28,719	84,206
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	1,482	52,846
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(31,062)	(74,556)
Other comprehensive income (loss)	(29,580)	(21,710)
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	3,920		4,327
Other comprehensive income (loss)	(407)	9,467
Entergy Louisiana [Member] | Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	(407)	9,467
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	3,920	14,029	$ 4,327	$ 4,562
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	10,050
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(407)	(583)
Other comprehensive income (loss)	$ (407)	$ 9,467

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Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,844,838	$ 2,427,179
Other Nonoperating Income (Expense)	(60,929)	23,389
Income taxes (benefits)	(65,942)	71,194
Consolidated net income	339,145	123,294
Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	248,250	332,565
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	7,481	56,975
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	39,319	94,375
Income taxes (benefits)	(8,257)	(19,819)
Consolidated net income	31,062	74,556
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	39,367	94,423
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]
Realized gain (loss)	(972)	3,116
Income taxes (benefits)	358	(1,147)
Consolidated net income	(614)	1,969
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	5,248	3,719
Amortization of loss	(34,529)	(27,318)
INCOME (LOSS) BEFORE INCOME TAXES	(29,281)	(23,599)
Income taxes (benefits)	6,314	4,049
Consolidated net income	(22,967)	(19,550)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,107,644	930,647
Other Nonoperating Income (Expense)	(34,638)	49,601
Income taxes (benefits)	(37,772)	50,183
Consolidated net income	166,626	189,396
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	1,230	1,089
Amortization of loss	(679)	(301)
INCOME (LOSS) BEFORE INCOME TAXES	551	788
Income taxes (benefits)	(144)	(205)
Consolidated net income	$ 407	$ 583

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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
	May 31, 2021 USD ($)	Apr. 30, 2021 USD ($)	Mar. 31, 2021 USD ($)	Mar. 31, 2021 USD ($)	May 01, 2021	Dec. 31, 2020 USD ($)
Debt Instrument [Line Items]
Amount of Facility			$ 3,500,000	$ 3,500,000
Amount Drawn/ Outstanding			$ 55,000	$ 55,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate			0.34%	0.34%
Commercial Paper program limit			$ 2,000,000	$ 2,000,000
Commercial Paper Amount Outstanding			1,028,000	1,028,000
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				1.63%
1.90% Series senior notes due June 2028
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			1.90%	1.90%
Amount			$ 650,000	$ 650,000
2.40% Series senior notes due June 2031
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			2.40%	2.40%
Amount			$ 650,000	$ 650,000
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			400	400
Entergy Arkansas [Member] | Revolving Credit Facility
Debt Instrument [Line Items]
Amount of Facility			150,000	150,000
Entergy Arkansas [Member] | Short-term revolving credit facility
Debt Instrument [Line Items]
Amount of Facility			$ 25,000	$ 25,000
Entergy Arkansas [Member] | 3.35% Series mortgage bonds due June 2052
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.35%	3.35%
Proceeds from Issuance of Debt			$ 400,000
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
Letters of Credit Outstanding, Amount			$ 200	$ 200		$ 300
Entergy Louisiana [Member] | 2.35% Series mortgage bonds due June 2032
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			2.35%	2.35%
Proceeds from Issuance of Debt			$ 500,000
Entergy Louisiana [Member] | 4.80% Series mortgage bonds due May 2021
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			4.80%	4.80%
Repayments of Debt			$ 200,000
Entergy Louisiana [Member] | 3.10% Series mortgage bonds due June 2041
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.10%	3.10%
Proceeds from Issuance of Debt			$ 500,000
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings			175,000	$ 175,000
Letters of Credit Outstanding, Amount			400	400		200
Non-MISO letter of credit outstanding			$ 1,000	$ 1,000
Entergy Mississippi [Member] | 3.50% Series mortgage bonds due June 2051 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.50%	3.50%
Proceeds from Issuance of Debt			$ 200,000
Entergy Mississippi [Member] | Revolving Credit Facility
Debt Instrument [Line Items]
Amount of Facility			82,500	$ 82,500
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						500
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
Letters of Credit Outstanding, Amount			100	100		$ 200
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			63,400	$ 63,400
Line of Credit Facility, Interest Rate During Period				1.23%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.125%
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			$ 4,800	$ 4,800
Line of Credit Facility, Interest Rate During Period				1.26%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.125%
Entergy Arkansas VIE [Member] | Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.65%	3.65%
Amount			$ 90,000	$ 90,000
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			73,200	$ 73,200
Line of Credit Facility, Interest Rate During Period				1.25%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.125%
Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			$ 70,500	$ 70,500
Line of Credit Facility, Interest Rate During Period				1.24%
Line of credit facility commitment fee as a percentage of undrawn commitment amount				0.125%
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage				0.225%
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				1.21%
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				1.21%
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				1.58%
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				1.58%
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				1.58%
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				1.58%
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				2.75%
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				1.36%
Subsequent Event [Member] | Entergy Louisiana [Member] | 2.00% pollution control refunding revenue bonds due June 2030
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		2.00%
Proceeds from Issuance of Debt		$ 16,200
Subsequent Event [Member] | Entergy Louisiana [Member] | 2.50% pollution control refunding revenue bonds due April 2036
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		2.50%
Proceeds from Issuance of Debt		$ 182,480
Subsequent Event [Member] | Entergy Louisiana [Member] | 3.375% Pollution contol refunding revenue bonds due 2028
Debt Instrument [Line Items]
Repayments of Debt		83,680
Subsequent Event [Member] | Entergy Louisiana [Member] | 3.50% Pollution control refunding revenue bond due 2030
Debt Instrument [Line Items]
Repayments of Debt		$ 115,000
Subsequent Event [Member] | Entergy Texas [Member] | 2.55% Series mortgage bonds due June 2021 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					2.55%
Repayments of Debt	$ 125,000
Credit Facility of Sixty Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount			1,000	$ 1,000
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) $ in Millions	Mar. 31, 2021 USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	55
Letters of Credit	6
Capacity Available	$ 3,439

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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, 2021	Dec. 31, 2020
Amount of Facility	$ 3,500.0
Amount Drawn/ Outstanding	55.0
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	5.0
Letters of Credit Outstanding, Amount	0.4
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member]
Amount of Facility	$ 25.0
Interest Rate	2.75%
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	1.21%
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
Letters of Credit Outstanding, Amount	0.2	$ 0.3
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Amount of Facility	$ 350.0
Interest Rate	1.21%
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	1.58%
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	1.58%
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	1.58%
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
Letters of Credit Outstanding, Amount	0.1	0.2
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Amount of Facility	$ 25.0
Interest Rate	1.36%
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		$ 0.5
Entergy Texas [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	$ 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, 2021 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	175
Borrowings	0
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	150
Borrowings	25
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	31
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

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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, 2021 USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 55.0
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	1.26%
Amount Drawn/ Outstanding	$ 4.8
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.125%
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	1.23%
Amount Drawn/ Outstanding	$ 63.4
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.125%
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	1.24%
Amount Drawn/ Outstanding	$ 70.5
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.125%
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	1.25%
Amount Drawn/ Outstanding	$ 73.2
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.125%

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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, 2021 USD ($)
Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.65%
Amount	$ 90
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

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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, 2021	Dec. 31, 2020
Long-term Debt, Fair Value	$ 25,716,967	$ 24,813,818
Long-term Debt, Book Value	24,704,475	22,369,776
Entergy Arkansas [Member]
Long-term Debt, Fair Value	4,126,514	4,355,632
Long-term Debt, Book Value	3,958,751	3,967,507
Entergy Louisiana [Member]
Long-term Debt, Fair Value	10,681,713	10,258,294
Long-term Debt, Book Value	10,059,885	9,027,451
Entergy Mississippi [Member]
Long-term Debt, Fair Value	2,084,891	2,021,432
Long-term Debt, Book Value	1,981,429	1,780,577
Entergy New Orleans [Member]
Long-term Debt, Fair Value	584,475	620,634
Long-term Debt, Book Value	642,412	642,233
Entergy Texas [Member]
Long-term Debt, Fair Value	2,545,973	2,765,193
Long-term Debt, Book Value	2,465,827	2,493,708
System Energy [Member]
Long-term Debt, Fair Value	785,758	840,540
Long-term Debt, Book Value	$ 768,969	$ 805,274

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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, 2021	Dec. 31, 2020
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	$ 0.4
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	0.4	$ 0.2
Entergy Louisiana [Member]
Letters of Credit Outstanding, Amount	0.2	0.3
Entergy New Orleans [Member]
Letters of Credit Outstanding, Amount	0.1	0.2
Entergy Texas [Member]
Letters of Credit Outstanding, Amount		$ 0.5
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	$ 1.0
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 50.0
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 30.2
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	$ 2.0
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	$ 12.8
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	$ 1.0

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Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions		1 Months Ended	3 Months Ended
	Jan. 28, 2021	Jan. 31, 2021	Mar. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years			3 years
2019 Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)			508,704
Weighted-average grant-date fair value of options granted (in dollars per share)			$ 12.27
Stock options outstanding			2,890,582
Weighted-average exercise price of stock options outstanding (in dollars per share)			$ 90.75
Intrinsic value in the money stock options			$ 41.6
Restricted Awards [Member] | 2019 Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted		392,382
Restricted stock awards granted value (in dollars per share)		$ 95.87
Long Term Incentive Plan [Member] | 2019 Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-term incentive plan awards		203,983
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] | 2019 Omnibus Incentive Plan | 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)	$ 110.74
Long Term Incentive Plan [Member] | 2019 Omnibus Incentive Plan | 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)	$ 95.87

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Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.0	$ 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

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Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Other Equity Awards [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 10.8	$ 9.4
Tax benefit recognized in Entergy's net income	2.7	2.4
Compensation cost capitalized as part of fixed assets and inventory	$ 4.0	$ 3.4

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Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2021
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 356,000
Defined Benefit Plan, Plan Assets, Contributions by Employer	152,200
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	66,649
Defined Benefit Plan, Plan Assets, Contributions by Employer	21,361
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	59,882
Defined Benefit Plan, Plan Assets, Contributions by Employer	29,159
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	13,715
Defined Benefit Plan, Plan Assets, Contributions by Employer	4,799
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	5,395
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,629
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	6,955
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,935
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	18,663
Defined Benefit Plan, Plan Assets, Contributions by Employer	6,675
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			$ 45,288
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			30,723
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			8,916
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			2,766
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			4,020
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			$ 11,988
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	4,600	$ 4,500
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	90	83
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	44	37
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	96	90
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	8	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	$ 115	$ 117

XML

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 45,241	$ 40,379
Interest cost on projected benefit obligation	46,099	60,799
Expected return on assets	(105,713)	(103,565)
Amortization of loss	104,392	87,259
Net other postretirement benefit cost	90,019	84,872
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	7,418	6,566
Interest cost on projected benefit obligation	8,341	11,433
Expected return on assets	(19,670)	(19,622)
Amortization of loss	19,303	16,897
Net other postretirement benefit cost	15,392	15,274
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	10,043	8,794
Interest cost on projected benefit obligation	9,562	12,841
Expected return on assets	(22,538)	(22,402)
Amortization of loss	19,204	16,627
Net other postretirement benefit cost	16,271	15,860
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	2,364	2,023
Interest cost on projected benefit obligation	2,462	3,340
Expected return on assets	(5,587)	(5,757)
Amortization of loss	5,668	4,748
Net other postretirement benefit cost	4,907	4,354
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	796	663
Interest cost on projected benefit obligation	1,029	1,456
Expected return on assets	(2,622)	(2,627)
Amortization of loss	2,270	2,005
Net other postretirement benefit cost	1,473	1,497
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,801	1,546
Interest cost on projected benefit obligation	1,949	2,782
Expected return on assets	(5,237)	(5,486)
Amortization of loss	3,711	3,265
Net other postretirement benefit cost	2,224	2,107
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	2,314	1,965
Interest cost on projected benefit obligation	2,142	2,814
Expected return on assets	(4,778)	(4,663)
Amortization of loss	5,326	4,279
Net other postretirement benefit cost	5,004	4,395
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,645	5,801
Interest cost on projected benefit obligation	5,320	7,932
Expected return on assets	(10,805)	(10,328)
Amortization of prior service cost (credit)	(8,267)	(5,922)
Amortization of loss	713	468
Net other postretirement benefit cost	(6,394)	(2,049)
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,034	828
Interest cost on projected benefit obligation	932	1,217
Expected return on assets	(4,505)	(4,326)
Amortization of prior service cost (credit)	(280)	(661)
Amortization of loss	49	55
Net other postretirement benefit cost	(2,770)	(2,887)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,544	1,423
Interest cost on projected benefit obligation	1,130	1,723
Expected return on assets	0	0
Amortization of prior service cost (credit)	(1,230)	(1,089)
Amortization of loss	(91)	(199)
Net other postretirement benefit cost	1,353	1,858
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	362	351
Interest cost on projected benefit obligation	278	422
Expected return on assets	(1,384)	(1,307)
Amortization of prior service cost (credit)	(444)	(321)
Amortization of loss	19	29
Net other postretirement benefit cost	(1,169)	(826)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	109	105
Interest cost on projected benefit obligation	130	227
Expected return on assets	(1,438)	(1,355)
Amortization of prior service cost (credit)	(229)	(76)
Amortization of loss	(178)	(38)
Net other postretirement benefit cost	(1,606)	(1,137)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	346	303
Interest cost on projected benefit obligation	317	582
Expected return on assets	(2,548)	(2,435)
Amortization of prior service cost (credit)	(936)	(550)
Amortization of loss	100	212
Net other postretirement benefit cost	(2,721)	(1,888)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	335	294
Interest cost on projected benefit obligation	220	307
Expected return on assets	(789)	(748)
Amortization of prior service cost (credit)	(109)	(219)
Amortization of loss	15	20
Net other postretirement benefit cost	(328)	(346)
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	4,600	4,500
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	90	83
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	44	37
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	96	90
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	8	8
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 115	$ 117

XML

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Mar. 31, 2021	Dec. 31, 2021
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 356,000
Defined Benefit Plan, Plan Assets, Contributions by Employer	152,200
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	59,882
Defined Benefit Plan, Plan Assets, Contributions by Employer	29,159
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		$ 30,723
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	13,715
Defined Benefit Plan, Plan Assets, Contributions by Employer	4,799
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		8,916
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	5,395
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,629
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		2,766
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	6,955
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,935
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		4,020
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	18,663
Defined Benefit Plan, Plan Assets, Contributions by Employer	6,675
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		11,988
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	66,649
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 21,361
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		$ 45,288

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Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 5,248	$ 3,719
Amortization of loss	(34,529)	(27,318)
Total	(29,281)	(23,599)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,230	1,089
Amortization of loss	(679)	(301)
Total	551	788
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(33,439)	(26,462)
Total	(33,439)	(26,462)
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(769)	(499)
Total	(769)	(499)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	5,288	3,776
Amortization of loss	(495)	(25)
Total	4,793	3,751
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,230	1,089
Amortization of loss	91	199
Total	1,321	1,288
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(40)	(57)
Amortization of loss	(595)	(831)
Total	(635)	(888)
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) - USD ($) $ in Millions	3 Months Ended		9 Months Ended	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2021	Dec. 31, 2022
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 3	$ 5
Restructuring Charges	13	21
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	13
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			$ 40	$ 15
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 13	$ 21

XML

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,844,838	$ 2,427,179
Segment Financial Information
Income taxes (benefits)	65,942	(71,194)
Consolidated net income	339,145	123,294
Assets	58,667,628		$ 58,239,212
Utility [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,596,616	2,094,629
Segment Financial Information
Income taxes (benefits)	59,734	(52,949)
Consolidated net income	360,600	323,849
Assets	56,086,185		55,940,153
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	248,219	332,549
Segment Financial Information
Income taxes (benefits)	15,560	(30,540)
Consolidated net income	38,124	(110,428)
Assets	3,793,754		3,800,378
All Other [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	23	11
Segment Financial Information
Income taxes (benefits)	(9,352)	12,295
Consolidated net income	(27,680)	(58,228)
Assets	867,301		552,632
Eliminations
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(20)	(10)
Segment Financial Information
Income taxes (benefits)	0	0
Consolidated net income	(31,899)	$ (31,899)
Assets	$ (2,079,612)		$ (2,053,951)

XML

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 13
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	13	$ 21
Restructuring Reserve	171	164	$ 159	$ 143
Payments for Restructuring	1	0
Asset Write-Offs, Impairments, And Related Charges	3	5
Entergy Wholesale Commodities [Member] | Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	13	21
Restructuring Reserve	157	150	145	129
Payments for Restructuring	1	0
Entergy Wholesale Commodities [Member] | Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	0	0
Restructuring Reserve	14	14	$ 14	$ 14
Payments for Restructuring	$ 0	$ 0

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Risk Management and Fair Values (Narrative) (Details) TWh in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Mar. 31, 2021 USD ($) GWh MMBTU counterparty	Mar. 31, 2020 USD ($)	Dec. 31, 2021 TWh	Dec. 31, 2020 USD ($)
Maturity of cash flow hedges, Tax	$ 8.0	$ 20.0
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	41,296,000
Total volume of fixed transmission rights outstanding | GWh	23,009
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings	$ 0.7	1.0
Debt Securities, Available-for-sale, Allowance for Credit Loss	6.4			$ 0.1
Letters Of Credit	$ 6.0
Number of Derivative Contract Counterparties in a Liability Position | counterparty	1
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	$ 0.4
Total volume of fixed transmission rights outstanding | GWh	5,765
Entergy Louisiana [Member]
Letters of Credit Outstanding, Amount	$ 0.2			0.3
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	21,920,000
Total volume of fixed transmission rights outstanding | GWh	10,716
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 0.4			0.2
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	19,376,000
Total volume of fixed transmission rights outstanding | GWh	2,576
Entergy New Orleans [Member]
Letters of Credit Outstanding, Amount	$ 0.1			0.2
Total volume of fixed transmission rights outstanding | GWh	1,055
Entergy Texas [Member]
Letters of Credit Outstanding, Amount				0.5
Total volume of fixed transmission rights outstanding | GWh	2,820
Entergy Wholesale Commodities [Member]
Letters of Credit Held				39.0
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	3 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	$ 94.0
Power Sales [Domain] | Cash Flow Hedging [Member] | Competitive Businesses Operating Revenues [Member]
Maturity of cash flow hedges, before taxes	0.3
Entergy Wholesale Commodities [Member]
Cash collateral posted	6.0			5.0
Letters of Credit Held	7.0			39.0
Letters Of Credit	1.0			$ 1.0
Hedging Liabilities, Current	$ 1.0
Subsequent Event [Member]
Planned generation sold forward from non utility nuclear power plants for the remainder of the period			98.00%
Planned Generation From Non Nuclear Power Plants Sold Forward Under Financial Hedges			12.00%
Total planned generation for remainder of the period | TWh			5.8

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Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	$ 6.0	$ 5.0
Liabilities:
Letters of Credit Held	7.0	39.0
Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1.0	1.0
Derivative, Collateral, Right to Reclaim Cash	0.0	0.0
Derivative Liability	1.0	1.0
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		1.0
Derivative Asset, Fair Value, Gross Asset		1.0
Derivative, Collateral, Obligation to Return Cash		0.0
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		38.0
Derivative Asset, Fair Value, Gross Asset		39.0
Derivative, Collateral, Obligation to Return Cash		(1.0)
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.0	1.0
Derivative Asset, Fair Value, Gross Asset	1.0	1.0
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	4.0	9.0
Derivative Asset, Fair Value, Gross Asset	4.0	9.0
Derivative, Collateral, Obligation to Return Cash		0.0
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		1.0
Derivative, Collateral, Right to Reclaim Cash		(1.0)
Derivative Liability		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	2.0	6.0
Derivative, Collateral, Right to Reclaim Cash	0.0	0.0
Derivative Liability	2.0	6.0
Entergy Louisiana [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.2	0.3
Entergy Louisiana [Member] | Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	0.8
Derivative, Collateral, Right to Reclaim Cash	0.0
Derivative Liability	0.8
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.4	0.5
Derivative Asset, Fair Value, Gross Asset	0.4	0.5
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	1.0	0.8
Derivative Asset, Fair Value, Gross Asset	1.0	0.8
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	1.2	4.2
Derivative Asset, Fair Value, Gross Asset	1.3	4.3
Derivative, Collateral, Obligation to Return Cash	0.1	(0.1)
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		0.3
Derivative, Collateral, Right to Reclaim Cash		0.0
Derivative Liability		0.3
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.4	0.2
Entergy Mississippi [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] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	2.3	5.0
Derivative, Collateral, Right to Reclaim Cash	0.0	0.0
Derivative Liability	2.3	5.0
Entergy New Orleans [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.1	0.2
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	0.2
Derivative, Collateral, Obligation to Return Cash	0.0	0.1
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		0.3
Derivative, Collateral, Right to Reclaim Cash		0.0
Derivative Liability		0.3
Entergy Arkansas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.4
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.4	2.7
Derivative Asset, Fair Value, Gross Asset	1.5	2.9
Derivative, Collateral, Obligation to Return Cash	(0.1)	(0.2)
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount		0.5
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.5	1.6
Derivative Asset, Fair Value, Gross Asset	0.5	1.6
Derivative, Collateral, Obligation to Return Cash	$ 0.0	$ 0.0

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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] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ 2	$ 67
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 39	$ 94

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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, 2021	Mar. 31, 2020	Dec. 31, 2020
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)	$ 0.0
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	7.0	(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	128.0	13.0
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	0.4
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	1.4		$ 2.7
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	26.1	4.6
Entergy Louisiana [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	0.2		0.3
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	1.2		4.2
Entergy Louisiana [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			0.3
Derivative, Collateral, Right to Reclaim Cash			0.0
Derivative Liability			0.3
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Noncurrent Liabilities
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Liability, Fair Value, Gross Liability			1.3
Derivative, Collateral, Right to Reclaim Cash			0.0
Derivative Liability			1.3
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	0.4		0.5
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	1.0		0.8
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	1.8	(1.3)
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	12.3	5.3
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	0.3		0.6
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	2.3		5.0
Derivative, Collateral, Right to Reclaim Cash	0.0		0.0
Derivative Liability	2.3		5.0
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	5.2	(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	7.2	(0.1)
Entergy New Orleans [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		0.2
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			0.3
Derivative, Collateral, Right to Reclaim Cash			0.0
Derivative Liability			0.3
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	(0.1)	(0.4)
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	1.3	0.4
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			0.5
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		$ 1.6
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	$ 77.9	$ 2.4

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Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	$ 1,675,082	$ 1,630,248
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	44,000	42,000
Replacement Reserve Escrow	103,000	148,000
Equity Securities, FV-NI	807,000	1,533,000
Debt Securities	3,436,000	2,617,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	9,172,000	9,122,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis	3,000	7,000
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	3,102,000	3,103,000
Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		38,000
Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000	2,000
Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	4,000	9,000
Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	1,675,000	1,630,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	44,000	42,000
Replacement Reserve Escrow	103,000	148,000
Equity Securities, FV-NI	807,000	1,533,000
Debt Securities	1,489,000	919,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	4,119,000	4,273,000
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	2,000	6,000
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000	1,000
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
Restricted Cash and Cash Equivalents, Current	0	0
Replacement Reserve Escrow	0	0
Equity Securities, FV-NI	0	0
Debt Securities	1,947,000	1,698,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,947,000	1,699,000
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	1,000	1,000
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	1,000
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
Restricted Cash and Cash Equivalents, Current	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	4,000	47,000
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	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		38,000
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	4,000	9,000
Entergy New Orleans [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	6,779	3,364
Replacement Reserve Escrow	38,800	83,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	45,700	86,500
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		300
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]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	6,800	3,400
Replacement Reserve Escrow	38,800	83,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	45,600	86,400
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		300
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]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Replacement Reserve Escrow	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]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Replacement Reserve Escrow	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	76,705	7
Assets at fair value on a recurring basis
Replacement Reserve Escrow	64,600	64,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	141,600	65,200
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis	2,300	5,000
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	300	600
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	76,700
Assets at fair value on a recurring basis
Replacement Reserve Escrow	64,600	64,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	141,300	64,600
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	2,300	5,000
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	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	300	600
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	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	300	600
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	601,583	726,717
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	8,800	2,700
Equity Securities, FV-NI	68,800	8,700
Debt Securities	632,800	632,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	2,492,300	2,528,900
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis	800	1,600
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	1,177,700	1,153,100
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,400	1,300
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,200	4,200
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	601,600	726,700
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	8,800	2,700
Equity Securities, FV-NI	68,800	8,700
Debt Securities	218,900	172,400
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	899,100	911,300
Entergy Louisiana [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	0	300
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000	800
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
Restricted Cash and Cash Equivalents, Current	0	0
Equity Securities, FV-NI	0	0
Debt Securities	413,900	459,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	414,300	460,300
Entergy Louisiana [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	800	1,300
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	400	500
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
Restricted Cash and Cash Equivalents, Current	0	0
Equity Securities, FV-NI	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,200	4,200
Entergy Louisiana [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	0
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	1,200	4,200
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	123,658	168,020
Assets at fair value on a recurring basis
Equity Securities, FV-NI	53,300	1,300
Debt Securities	425,900	447,900
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,436,200	1,444,600
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	831,900	824,700
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,400	2,700
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	123,700	168,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	53,300	1,300
Debt Securities	89,900	98,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	266,900	267,500
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	336,000	349,700
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	336,000	349,700
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	1,400	2,700
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,400	2,700
Entergy Texas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	248,570
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	28,072	36,233
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	28,600	286,400
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	500	1,600
Entergy Texas [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		248,600
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	28,100	36,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	28,100	284,800
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]
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
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]
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
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	500	1,600
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	1,600
System Energy [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	132,149	216,383
Assets at fair value on a recurring basis
Equity Securities, FV-NI	60,600	3,800
Debt Securities	406,400	427,700
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,381,900	1,432,300
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	782,800	784,400
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	132,100	216,400
Assets at fair value on a recurring basis
Equity Securities, FV-NI	60,600	3,800
Debt Securities	179,400	177,300
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	372,100	397,500
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	227,000	250,400
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	227,000	250,400
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

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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, 2021	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
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	$ 85.0	$ 38.0	$ 118.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	2.0	67.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0.0	0.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(38.0)	(82.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings	(2.0)	(18.0)
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	4.0	4.0	9.0	10.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	4.0	0.0
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	119.0	7.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(128.0)	(13.0)
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	1.4	1.1	2.7	3.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		2.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	24.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(26.1)	(4.6)
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	1.2	1.9	4.2	4.5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		2.7
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	9.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(12.3)	(5.3)
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	0.3	0.3	0.6	0.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	6.9
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements		(0.1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	7.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings		(0.6)
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	0.0	0.1	0.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		0.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	1.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	1.2	0.4
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	0.3	$ 1.6	$ 0.9
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		1.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	76.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	$ (77.9)	$ (2.4)

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Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) - Gas Hedge Contracts [Member]	3 Months Ended
	Mar. 31, 2021
Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	3 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, 2021	Mar. 31, 2020	Dec. 31, 2020
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	$ (25,581)	$ 8,743
Amortized cost of debt securities	$ 3,376,000		$ 2,423,000
Average coupon rate of debt securities	2.59%
Average duration of debt securities, years	5 years 11 months 23 days
Average maturity of debt securities, years	8 years 5 months 12 days
Proceeds from the dispositions of debt securities	$ 524,000	400,000
Gains from dispositions of debt securities, gross	11,000	14,000
Losses from dispositions of debt securities, gross	11,000	3,000
Debt Securities, Available-for-sale, Allowance for Credit Loss	6,400		100
Equity Securities, FV-NI, Unrealized Gain	200,000
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	5,000		31,000
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 419,500		420,400
Average coupon rate of debt securities	2.42%
Average duration of debt securities, years	6 years 4 months 24 days
Average maturity of debt securities, years	7 years 7 months 13 days
Proceeds from the dispositions of debt securities	$ 13,800	48,600
Gains from dispositions of debt securities, gross	800	4,500
Losses from dispositions of debt securities, gross	100	200
Equity Securities, FV-NI, Unrealized Gain	45,200
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 606,300		581,400
Average coupon rate of debt securities	3.25%
Average duration of debt securities, years	6 years 7 months 2 days
Average maturity of debt securities, years	11 years 6 months 21 days
Proceeds from the dispositions of debt securities	$ 108,400	67,400
Gains from dispositions of debt securities, gross	3,300	2,900
Losses from dispositions of debt securities, gross	$ 3,200	600
Percentage Interest in River Bend	30.00%
Equity Securities, FV-NI, Unrealized Gain	$ 64,900
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 397,000		398,400
Average coupon rate of debt securities	2.36%
Average duration of debt securities, years	6 years 3 months 21 days
Average maturity of debt securities, years	9 years 7 months 13 days
Proceeds from the dispositions of debt securities	$ 74,100	92,000
Gains from dispositions of debt securities, gross	1,200	1,700
Losses from dispositions of debt securities, gross	1,600	$ 200
Equity Securities, FV-NI, Unrealized Gain	43,100
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	970,000		991,000
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	631,000		631,000
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	760,000		794,000
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 545,000		$ 554,000

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Decommissioning Trust Funds (Securities Held) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Fair Value	$ 3,436.0	$ 2,617.0
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	102.0	197.0
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	43.0	3.0
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	425.9	447.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	13.2	27.7
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	6.8	0.3
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	632.8	632.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	31.2	51.3
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	4.6	0.5
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	406.4	427.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	14.3	30.0
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 5.0	$ 0.8

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Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	$ 1,748.0	$ 187.0
More than 12 months Fair Value	3.0	2.0
Total Fair Value	1,751.0	189.0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	43.0	3.0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.0	0.0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	43.0	3.0
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	139.1	29.9
More than 12 months Fair Value	0.0	0.0
Total Fair Value	139.1	29.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	6.8	0.3
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.0	0.0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	6.8	0.3
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	171.7	36.4
More than 12 months Fair Value	2.3	0.8
Total Fair Value	174.0	37.2
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	4.6	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.0	0.0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	4.6	0.5
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	157.5	28.9
More than 12 months Fair Value	0.0	0.0
Total Fair Value	157.5	28.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	5.0	0.8
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.0	0.0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 5.0	$ 0.8

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Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Fair value of debt securities by contractual maturities
1 year - 5 years	$ 1,027.0	$ 672.0
5 years - 10 years	1,257.0	852.0
10 years - 15 years	492.0	377.0
15 years - 20 years	128.0	144.0
20 years+	532.0	576.0
Total	3,436.0	2,617.0
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	0.0
Debt Securities, Available-for-Sale, Maturity, Allocated and Single Maturity Date, within One Year, Negative Fair Value		(4.0)
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	84.7	113.1
5 years - 10 years	179.2	189.8
10 years - 15 years	100.8	81.4
15 years - 20 years	26.7	28.5
20 years+	34.5	35.1
Total	425.9	447.9
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	0.0	0.0
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	89.3	117.0
5 years - 10 years	186.0	159.4
10 years - 15 years	113.7	101.2
15 years - 20 years	63.4	66.9
20 years+	180.4	187.7
Total	632.8	632.2
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	0.0	0.0
System Energy [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	136.2	134.7
5 years - 10 years	120.4	141.5
10 years - 15 years	35.1	31.5
15 years - 20 years	4.5	5.3
20 years+	110.2	115.8
Total	406.4	427.7
Debt Securities, Available-for-Sale, Maturity, Allocated and Single Maturity Date, within One Year, Negative Fair Value	$ 0.0	$ (1.1)

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Income Taxes Income Taxes (Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 41	$ 30
Entergy Arkansas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	8	13
Entergy Louisiana [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	8	8
Entergy New Orleans [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	0	3
Entergy Texas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	7	6
System Energy [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 18	$ 0

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Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Construction expenditures in accounts payable	$ 496.4	$ 745.0
Entergy Arkansas [Member]
Construction expenditures in accounts payable	39.6	59.7
Entergy Louisiana [Member]
Construction expenditures in accounts payable	330.4	460.5
Entergy Mississippi [Member]
Construction expenditures in accounts payable	24.1	31.4
Entergy New Orleans [Member]
Construction expenditures in accounts payable	4.0	9.2
Entergy Texas [Member]
Construction expenditures in accounts payable	44.6	116.8
System Energy [Member]
Construction expenditures in accounts payable	$ 17.7	$ 17.7

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Variable Interest Entities (Narrative) (Details) - System Energy [Member] - Grand Gulf [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Variable Interest Entity [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage	11.50%
Payments on lease, including interest	$ 8.6	$ 8.6

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Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,844,838	$ 2,427,179
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	3,200	6,600
Accounts Receivable, Allowance for Credit Loss, Writeoff	(3,800)	(8,400)
Accounts Receivable, Allowance for Credit Loss, Recovery	1,900	2,900
Allowance for Doubtful Other Receivables, Current	119,000	8,500	$ 117,700	$ 7,400
Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,538,420	2,050,638
Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	58,168	43,976
Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	248,250	332,565
Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	966,855	798,028
Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	572,676	538,940
Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	597,652	557,515
Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	56,798	52,582
Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	205,075	53,725
Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	80,261	50,166
Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	59,103	(318)
Non-Customer [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	16,137	116,563
Competitive Business Sales [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	232,113	216,002
Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,193,981	1,947,065
Customer | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,479,317	2,050,956
Entergy Arkansas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	583,386	481,912
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	2,400	1,200
Accounts Receivable, Allowance for Credit Loss, Writeoff	(100)	(1,800)
Accounts Receivable, Allowance for Credit Loss, Recovery	600	900
Allowance for Doubtful Other Receivables, Current	21,200	1,500	18,300	1,200
Regulatory asset related to costs associated with COVID-19 pandemic	11,400
Entergy Arkansas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	583,386	481,912
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Entergy Arkansas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	237,182	219,688
Entergy Arkansas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	106,416	111,245
Entergy Arkansas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	103,412	101,088
Entergy Arkansas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,256	4,030
Entergy Arkansas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	110,085	41,140
Entergy Arkansas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	19,583	1,596
Entergy Arkansas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,452	3,125
Entergy Arkansas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	451,266	436,051
Entergy Arkansas [Member] | Customer | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	580,934	478,787
Entergy Louisiana [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,107,644	930,647
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	2,300	3,000
Accounts Receivable, Allowance for Credit Loss, Writeoff	(2,100)	(3,500)
Accounts Receivable, Allowance for Credit Loss, Recovery	700	1,100
Allowance for Doubtful Other Receivables, Current	46,600	2,500	45,700	1,900
Regulatory asset related to costs associated with COVID-19 pandemic	47,800
Entergy Louisiana [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,079,663	912,541
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	27,981	18,106
Entergy Louisiana [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	335,760	259,860
Entergy Louisiana [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	224,649	202,246
Entergy Louisiana [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	347,009	322,342
Entergy Louisiana [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	18,616	16,754
Entergy Louisiana [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	80,428	78,530
Entergy Louisiana [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	43,910	32,008
Entergy Louisiana [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	29,291	801
Entergy Louisiana [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	926,034	801,202
Entergy Louisiana [Member] | Customer | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,050,372	911,740
Entergy Mississippi [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	336,619	293,922
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	(2,200)	900
Accounts Receivable, Allowance for Credit Loss, Writeoff	(800)	(1,200)
Accounts Receivable, Allowance for Credit Loss, Recovery	300	300
Allowance for Doubtful Other Receivables, Current	16,800	600	19,500	600
Regulatory asset related to costs associated with COVID-19 pandemic	16,300
Entergy Mississippi [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	336,619	293,922
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Entergy Mississippi [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	147,636	127,102
Entergy Mississippi [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	97,936	96,798
Entergy Mississippi [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	33,980	36,390
Entergy Mississippi [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	10,543	10,327
Entergy Mississippi [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	40,311	14,422
Entergy Mississippi [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	3,950	6,443
Entergy Mississippi [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,263	2,440
Entergy Mississippi [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	290,095	270,617
Entergy Mississippi [Member] | Customer | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	334,356	291,482
Entergy New Orleans [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	169,335	149,302
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	1,800	800
Accounts Receivable, Allowance for Credit Loss, Writeoff	0	(800)
Accounts Receivable, Allowance for Credit Loss, Recovery	200	200
Allowance for Doubtful Other Receivables, Current	19,400	3,400	17,400	3,200
Regulatory asset related to costs associated with COVID-19 pandemic	14,800
Entergy New Orleans [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	139,148	123,431
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	30,187	25,871
Entergy New Orleans [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	66,427	50,899
Entergy New Orleans [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	47,799	45,505
Entergy New Orleans [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	6,789	7,347
Entergy New Orleans [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	16,380	15,851
Entergy New Orleans [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,696	10,170
Entergy New Orleans [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	(3,359)	763
Entergy New Orleans [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	416	(7,104)
Entergy New Orleans [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	137,395	119,602
Entergy New Orleans [Member] | Customer | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	138,732	130,535
Entergy Texas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	480,220	339,336
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	(1,100)	700
Accounts Receivable, Allowance for Credit Loss, Writeoff	(800)	(1,100)
Accounts Receivable, Allowance for Credit Loss, Recovery	100	500
Allowance for Doubtful Other Receivables, Current	15,000	600	$ 16,800	$ 500
Regulatory asset related to costs associated with COVID-19 pandemic	10,700
Entergy Texas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	480,220	339,336
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Entergy Texas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	179,850	140,480
Entergy Texas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	95,876	83,146
Entergy Texas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	106,462	90,348
Entergy Texas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	7,003	5,620
Entergy Texas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	74,073	8,629
Entergy Texas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	17,529	10,702
Entergy Texas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	(573)	411
Entergy Texas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	389,191	319,594
Entergy Texas [Member] | Customer | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	480,793	338,925
System Energy [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 117,746	$ 130,664

XML

Label	Element	Value
Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 9,257,190,000
AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(446,920,000)
Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	2,700,000
Subsidiaries Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	35,000,000
Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,154,150,000)
Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	6,564,436,000
Accounting Standards Update 2016-13 [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(419,000)
Accounting Standards Update 2016-13 [Member] | Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(419,000)
Accounting Standards Update 2016-13 [Member] | AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | Subsidiaries Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 0