10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(MARK ONE)

x QUARTERLY REPORT PURSUANT TO SECTION 13, 15(d), OR 37 OF THE

SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended December 31, 2023

OR

 o 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 000-52313

TENNESSEE VALLEY AUTHORITY

(Exact name of registrant as specified in its charter)

A corporate agency of the United States created by an act of Congress (State or other jurisdiction of incorporation or organization)	62-0474417  (I.R.S. Employer Identification No.)
400 W. Summit Hill Drive Knoxville, Tennessee  (Address of principal executive offices)	37902  (Zip Code)

(865) 632-2101

(Registrant's telephone number, including area code)

None

(Former name, former address and former fiscal year, if changed since last report)

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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
N/A	N/A	N/A

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13, 15(d), or 37 of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No o

Indicate by check mark whether the registrant has 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 registrant was required to submit such files).

Yes x No o

Indicate by check mark whether the 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 Exchange Act.

Large accelerated filer  o                                                                                    Accelerated filer o

Non-accelerated filer    x   Smaller reporting company  o        

Emerging growth company o

If an emerging growth company, indicate by check mark if the registrant has 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. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes o   No x

Number of shares of common stock outstanding at January 29, 2024: N/A

1

Table of Contents
	Page
GLOSSARY OF COMMON ACRONYMS......................................................................................................................................	3
FORWARD-LOOKING INFORMATION.........................................................................................................................................	4
GENERAL INFORMATION............................................................................................................................................................	6
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.............................................................................................................................................	7
Consolidated Statements of Operations (Unaudited)............................................................................................................	7
Consolidated Statements of Comprehensive Income (Loss) (Unaudited)............................................................................	7
Consolidated Balance Sheets (Unaudited)...........................................................................................................................	8
Consolidated Statements of Cash Flows (Unaudited)..........................................................................................................	10
Consolidated Statements of Changes in Proprietary Capital (Unaudited)............................................................................	11
Notes to Consolidated Financial Statements (Unaudited)....................................................................................................	12
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS...	40
Executive Overview...............................................................................................................................................................	40
Results of Operations............................................................................................................................................................	41
Liquidity and Capital Resources............................................................................................................................................	46
Key Initiatives and Challenges..............................................................................................................................................	48
Environmental Matters..........................................................................................................................................................	49
Legal Proceedings................................................................................................................................................................	50
Off-Balance Sheet Arrangements..........................................................................................................................................	50
Critical Accounting Estimates................................................................................................................................................	50
New Accounting Standards and Interpretations....................................................................................................................	50
Legislative and Regulatory Matters.......................................................................................................................................	50
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK..............................................................	51
ITEM 4. CONTROLS AND PROCEDURES..................................................................................................................................	51
Disclosure Controls and Procedures.....................................................................................................................................	51
Changes in Internal Control over Financial Reporting..........................................................................................................	51
PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS..................................................................................................................................................	51
ITEM 1A. RISK FACTORS............................................................................................................................................................	51
ITEM 5. OTHER INFORMATION..................................................................................................................................................	51
ITEM 6. EXHIBITS........................................................................................................................................................................	52
SIGNATURES...............................................................................................................................................................................	53

2

GLOSSARY OF COMMON ACRONYMS
Following are definitions of some of the terms or acronyms that may be used in this Quarterly Report on Form 10-Q for the quarter ended December 31, 2023 (the "Quarterly Report"):
Term or Acronym	Definition
AOCI	Accumulated other comprehensive income (loss)
ARO	Asset retirement obligation
ART	Asset Retirement Trust
Bonds	Bonds, notes, or other evidences of indebtedness
Bull Run	Bull Run Fossil Plant
CCR	Coal combustion residuals
Cumberland	Cumberland Fossil Plant
CVA	Credit valuation adjustment
CY	Calendar year
DCP	Deferred Compensation Plan
EO(s)	Executive Order(s)
FERC	Federal Energy Regulatory Commission
FHP	Financial Hedging Program
GAAP	Accounting principles generally accepted in the United States of America
GAC	Grid access charge
GEH	GE Hitachi Nuclear Energy
Holdco	John Sevier Holdco LLC
Jacobs	Jacobs Engineering Group, Inc.
JSCCG	John Sevier Combined Cycle Generation LLC
kWh	Kilowatt hours
LPCs	Local power company customers
MLGW	Memphis Light, Gas and Water Division
mmBtu	Million British thermal unit(s)
Moody's	Moody's Investors Service, Inc.
MtM	Mark-to-market
NAV	Net asset value
NDT	Nuclear Decommissioning Trust
NEIL	Nuclear Electric Insurance Limited
NES	Nashville Electric Service
NRC	Nuclear Regulatory Commission
PPA(s)	Power Purchase Agreement(s)
RFP(s)	Request(s) for proposals
RP	Restoration Plan
SCCG	Southaven Combined Cycle Generation LLC
SEC	Securities and Exchange Commission
SERP	Supplemental Executive Retirement Plan
SHLLC	Southaven Holdco LLC
TVA	Tennessee Valley Authority
TVA Act	Tennessee Valley Authority Act of 1933, as amended
TVA Board	TVA Board of Directors
U.S. Treasury	United States Department of the Treasury
VIE	Variable interest entity
XBRL	eXtensible Business Reporting Language

3

FORWARD-LOOKING INFORMATION

This Quarterly Report contains forward-looking statements relating to future events and future performance.  All statements other than those that are purely historical may be forward-looking statements.  In certain cases, forward-looking statements can be identified by the use of words such as "may," "will," "should," "expect," "anticipate," "believe," "intend," "project," "plan," "predict," "assume," "forecast," "estimate," "objective," "possible," "probably," "likely," "potential," "speculate," "aim," "aspiration," "goal," "seek," "strategy," "target," the negative of such words, or other similar expressions.

Although the Tennessee Valley Authority ("TVA") believes that the assumptions underlying any forward-looking statements are reasonable, TVA does not guarantee the accuracy of these statements.  Numerous factors could cause actual results to differ materially from those in any forward-looking statements.  These factors include, among other things:

•New, amended, or existing laws, regulations, executive orders ("EOs"), or administrative orders or interpretations, including those related to climate change and other environmental matters, and the costs of complying with these laws, regulations, EOs, or administrative orders or interpretations;

•The cost of complying with known, anticipated, or new environmental requirements, some of which could render continued operation of many of TVA's aging coal-fired generation units not cost-effective or result in their removal from service, perhaps permanently;

•Federal legislation aimed specifically at curtailing TVA's activities, including legislation that may cause TVA to lose its protected service territory, its sole authority to set rates, or its authority to manage the Tennessee River system or the real property currently entrusted to TVA; subject TVA to additional environmental regulation or additional requirements of the North American Electric Reliability Corporation ("NERC") or Federal Energy Regulatory Commission ("FERC"); require the divestiture of TVA or the sale of certain of TVA's assets; lower the debt ceiling on bonds, notes, or other evidences of indebtedness (collectively, "Bonds") specified in the Tennessee Valley Authority Act of 1933, as amended, ("TVA Act"); or restrict TVA's access to its funds;

•Cyber attacks on TVA's assets or the assets of third parties upon which TVA relies;

•The failure of TVA's information technology systems;

•Significant delays and additional costs, and/or inability to obtain necessary regulatory approvals, licenses, or permits, for major projects, including for assets that TVA needs to serve its existing and future load and to meet its carbon reduction aspirations;

•Limitations on TVA's ability to borrow money, which may result from, among other things, TVA's approaching or substantially reaching the debt ceiling or TVA's losing access to the debt markets, and which may impact TVA's ability to make planned capital investments;

•Events at a nuclear facility, whether or not operated by or licensed to TVA, which, among other things, could lead to increased regulation or restriction on the construction, ownership, operation, or decommissioning of nuclear facilities or on the storage of spent fuel, obligate TVA to pay retrospective insurance premiums, reduce the availability and affordability of insurance, increase the costs of operating TVA's existing nuclear units, or cause TVA to forego future construction at these or other facilities;

•Risks associated with the operation of nuclear facilities or other generation and related facilities, including coal combustion residuals ("CCR") facilities;

•Inability to continue to operate certain assets, especially nuclear facilities, including due to the inability to obtain, or loss of, regulatory approval for the operation of assets;

•Significant additional costs for TVA to manage and operate its CCR facilities;

•Physical attacks, threats, or other interference causing damage to TVA's facilities or interfering with TVA's operations;

•The failure of TVA's generation, transmission, navigation, flood control, and related assets and infrastructure, including CCR facilities and spent nuclear fuel storage facilities, to operate as anticipated, resulting in lost revenues, damages, or other costs that are not reflected in TVA's financial statements or projections, including due to aging or technological issues;

•Costs or liabilities that are not anticipated in TVA's financial statements for third-party claims, natural resource damages, environmental cleanup activities, or fines or penalties associated with unexpected events such as failures of a facility or infrastructure;

•Events at a TVA facility, which, among other things, could result in loss of life, damage to the environment, damage to or loss of the facility, or damage to the property of others;

•Events that negatively impact TVA's reliability, including problems at other utilities or at TVA facilities or the increase in intermittent sources of power;

•Events or changes involving transmission lines, dams, and other facilities not operated by TVA, including those that affect the reliability of the interstate transmission grid of which TVA's transmission system is a part and those that increase flows across TVA's transmission grid;

•Disruption of supplies of fuel, purchased power, or other critical items or services, which may result from, among other things, economic conditions, weather conditions, physical or cyber attacks, political developments, international trade restrictions or tariffs, legal actions, mine closures or reduced mine production, increases in fuel exports, environmental regulations affecting TVA's suppliers, transportation or delivery constraints, including limited transmission availability, shortages of raw materials, supply chain difficulties, labor shortages, strikes, inflation, or similar events and which may, among other things, hinder TVA's ability to operate its assets and to complete projects on time and on budget;

•Circumstances that cause TVA to change its determinations regarding the appropriate mix of generation assets;

4

•Costs or other challenges resulting from a failure by TVA to meet its carbon reduction aspirations;

•Actions taken, or inaction, by the United States ("U.S.") government relating to the national debt ceiling or automatic spending cuts in government programs;

•Inability to respond quickly enough to current or potential customer demands or needs or to act solely in the interest of ratepayers;

•Negative outcomes of current or future legal or administrative proceedings;

•Other unforeseeable occurrences negatively impacting TVA assets or their supporting infrastructure;

•The need for significant future contributions associated with TVA's pension plans, other post-retirement benefit plans, or health care plans;

•Increases in TVA's financial liabilities for decommissioning its nuclear facilities and retiring other assets;

•The requirement or decision to make additional contributions to TVA's Nuclear Decommissioning Trust ("NDT") or Asset Retirement Trust ("ART");

•Differences between estimates of revenues and expenses and actual revenues earned and expenses incurred;

•An increase in TVA's cost of capital, which may result from, among other things, changes in the market for Bonds, disruptions in the banking system or financial markets, changes in the credit rating of TVA or the U.S. government, or, potentially, an increased reliance by TVA on alternative financing should TVA approach its debt limit;

•The inaccuracy of certain assumptions about the future, including economic forecasts, anticipated energy and commodity prices, cost estimates, construction schedules, power demand forecasts, the appropriate generation mix to meet demand, and assumptions about potential regulatory environments;

•Significant decline in the demand for electricity that TVA produces, which may result from, among other things, economic downturns or recessions, loss of customers, reductions in demand for electricity generated from non-renewable sources or centrally located generation sources, increased utilization of distributed energy resources, increased energy efficiency and conservation, or improvements in alternative generation and energy storage technologies;

•Changes in customer preferences for energy produced from cleaner generation sources;

•Addition or loss of customers by TVA or TVA's local power company customers ("LPCs");

•Potential for increased demand for energy resulting from, among other things, an increase in the population of TVA's service area;

•Changes in technology, which, among other things, may affect relationships with customers and require TVA to change how it conducts its operations;

•Changes in the economy and volatility in financial markets;

•Reliability or creditworthiness of counterparties including but not limited to customers, suppliers, renewable resource providers, and financial institutions;

•Changes in the market price of commodities such as purchased power, coal, uranium, natural gas, fuel oil, crude oil, construction materials, reagents, or emission allowances;

•Changes in the market price of equity securities, debt securities, or other investments;

•Changes in interest rates, currency exchange rates, or inflation rates;

•Failure to attract or retain an appropriately qualified, diverse, and inclusive workforce;

•Changes in the membership of the TVA Board of Directors ("TVA Board") or TVA senior management, which may impact how TVA operates;

•Weather conditions, including changing weather patterns, extreme weather conditions, and other events such as flooding, droughts, wildfires, heat waves, and snow or ice storms that may result from climate change, which may hamper TVA's ability to supply power, cause customers' demand for power to exceed TVA's then-present power supply, or otherwise negatively impact net revenue;

•Events affecting the supply or quality of water from the Tennessee River system or Cumberland River system, or elsewhere, which could interfere with TVA's ability to generate power;

•Catastrophic events, such as fires, earthquakes, explosions, solar events, electromagnetic pulses, geomagnetic disturbances, droughts, floods, hurricanes, tornadoes, polar vortexes, icing events, pipeline explosions, or other casualty events, wars, national emergencies, terrorist activities, pandemics, widespread public health crises, geopolitical events, or other similar destructive or disruptive events;

•Inability to use regulatory accounting for certain costs;

•Ineffectiveness of TVA's financial control system to control issues and instances of fraud or to prevent or detect errors;

•Ineffectiveness of TVA's disclosure controls and procedures or its internal control over financial reporting;

•Adverse effects from regional health emergencies;

•Inability of TVA to implement its business strategy successfully, including due to the increased use in the public of distributed energy resources or energy-efficiency programs;

•Inability of TVA to adapt its business model to changes in the utility industry and customer preferences and to remain cost competitive;

•Inability of TVA to achieve or maintain its cost reduction goals, which may require TVA to increase rates and/or issue more debt than planned;

•The emergence of artificial intelligence and its potential application to various business practices, including TVA's operations and the operations of TVA's stakeholders;

•Loss of quorum of the TVA Board, which may limit TVA's ability to adapt to meet changing business conditions;

•Negative impacts on TVA's reputation; or

•Other unforeseeable events.

5

See also Part I, Item 1A, Risk Factors, and Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations in TVA's Annual Report on Form 10-K for the year ended September 30, 2023 (the "Annual Report"), and Part I, Item 2, Management's Discussion and Analysis of Financial Condition and Results of Operations in this Quarterly Report for a discussion of factors that could cause actual results to differ materially from those in any forward-looking statement.  New factors emerge from time to time, and it is not possible for TVA to predict all such factors or to assess the extent to which any factor or combination of factors may impact TVA's business or cause results to differ materially from those contained in any forward-looking statement.  TVA undertakes no obligation to update any forward-looking statement to reflect developments that occur after the statement is made, except as required by law.

GENERAL INFORMATION

Fiscal Year

References to years (2024, 2023, etc.) in this Quarterly Report are to TVA's fiscal years ending September 30.  Years that are preceded by "CY" are references to calendar years.

Notes

References to "Notes" are to the Notes to Consolidated Financial Statements contained in Part I, Item 1, Financial Statements in this Quarterly Report.

Available Information

TVA files annual, quarterly, and current reports with the Securities and Exchange Commission ("SEC") under Section 37 of the Securities Exchange Act of 1934 (the "Exchange Act"). TVA's SEC filings are available to the public at www.tva.com, free of charge, as soon as reasonably practicable after such reports are electronically filed with or furnished to the SEC.  Information contained on or accessible through TVA's website shall not be deemed to be incorporated into, or to be a part of, this Quarterly Report or any other report or document that TVA files with the SEC.  All TVA SEC reports are available to the public without charge from the website maintained by the SEC at www.sec.gov.  

6

PART I - FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

Three Months Ended December 31

(in millions)

	2023		2022
Operating revenues
Revenue from sales of electricity	$	2,731	$	2,963
Other revenue	34		52
Total operating revenues	2,765		3,015
Operating expenses
Fuel	496		615
Purchased power	359		491
Operating and maintenance	867		827
Depreciation and amortization	521		533
Tax equivalents	133		151
Total operating expenses	2,376		2,617
Operating income	389		398
Other income, net	23		16
Other net periodic benefit cost	23		51
Interest expense	262		262
Net income	$	127	$	101
The accompanying notes are an integral part of these consolidated financial statements.

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited)

Three Months Ended December 31

(in millions)

	2023		2022
Net income	$	127	$	101
Other comprehensive income (loss)
Net unrealized gain on cash flow hedges	20		71
Net unrealized gain reclassified to earnings from cash flow hedges	(19)		(34)
Total other comprehensive income	1		37
Total comprehensive income	$	128	$	138
The accompanying notes are an integral part of these consolidated financial statements.

7

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED BALANCE SHEETS (Unaudited)

(in millions)

ASSETS
	December 31, 2023		September 30, 2023
Current assets
Cash and cash equivalents	$	498	$	501
Accounts receivable, net	1,593		1,745
Inventories, net	1,182		1,108
Regulatory assets	251		178
Other current assets	152		134
Total current assets	3,676		3,666
Property, plant, and equipment
Completed plant	67,073		68,199
Less accumulated depreciation	(34,445)		(35,871)
Net completed plant	32,628		32,328
Construction in progress	3,425		3,238
Nuclear fuel	1,364		1,344
Finance leases	562		572
Total property, plant, and equipment, net	37,979		37,482
Investment funds	4,472		4,123
Regulatory and other long-term assets
Regulatory assets	5,551		5,566
Operating lease assets, net of amortization	258		177
Other long-term assets	312		330
Total regulatory and other long-term assets	6,121		6,073
Total assets	$	52,248	$	51,344
The accompanying notes are an integral part of these consolidated financial statements.

8

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED BALANCE SHEETS (Unaudited)

(in millions)

LIABILITIES AND PROPRIETARY CAPITAL
	December 31, 2023		September 30, 2023
Current liabilities
Accounts payable and accrued liabilities	$	2,451	$	2,618
Accrued interest	268		272
Asset retirement obligations	275		272
Regulatory liabilities	259		222
Short-term debt, net	1,042		432
Current maturities of power bonds	1,022		1,022
Current maturities of long-term debt of variable interest entities	35		35
Total current liabilities	5,352		4,873
Other liabilities
Post-retirement and post-employment benefit obligations	2,457		2,527
Asset retirement obligations	7,295		7,217
Finance lease liabilities	571		576
Other long-term liabilities	1,488		1,211
Regulatory liabilities	103		107
Total other liabilities	11,914		11,638
Long-term debt, net
Long-term power bonds, net	17,867		17,844
Long-term debt of variable interest entities, net	933		933
Total long-term debt, net	18,800		18,777
Total liabilities	36,066		35,288
Contingencies and legal proceedings (Note 20)
Proprietary capital
Power program appropriation investment	258		258
Power program retained earnings	15,429		15,302
Total power program proprietary capital	15,687		15,560
Nonpower programs appropriation investment, net	523		525
Accumulated other comprehensive loss	(28)		(29)
Total proprietary capital	16,182		16,056
Total liabilities and proprietary capital	$	52,248	$	51,344
The accompanying notes are an integral part of these consolidated financial statements.

9

TENNESSEE VALLEY AUTHORITY

 CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

 For the Three Months Ended December 31

 (in millions)

	2023		2022
Cash flows from operating activities
Net income	$	127	$	101
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization(1)	527		538
Amortization of nuclear fuel cost	99		88
Non-cash retirement benefit expense	33		63
Other regulatory amortization and deferrals	46		(69)
Changes in current assets and liabilities
Accounts receivable, net	153		256
Inventories and other current assets, net	(105)		(216)
Accounts payable and accrued liabilities	(289)		(86)
Accrued interest	(2)		(16)
Pension contributions	(75)		(75)
Other, net	(121)		(145)
Net cash provided by operating activities	393		439
Cash flows from investing activities
Construction expenditures	(863)		(605)
Nuclear fuel expenditures	(146)		(192)
Purchases of investments	(1)		—
Acquisition of leasehold interests in combustion turbine assets	—		(78)
Loans and other receivables
Advances	(4)		—
Repayments	2		3
Other, net	10		(4)
Net cash used in investing activities	(1,002)		(876)
Cash flows from financing activities
Long-term debt
Redemptions and repurchases of power bonds	(1)		(1)
Short-term debt issues, net	610		446
Payments on leases and leasebacks	(10)		(10)
Other, net	7		2
Net cash provided by financing activities	606		437
Net change in cash, cash equivalents, and restricted cash	(3)		—
Cash, cash equivalents, and restricted cash at beginning of period	521		520
Cash, cash equivalents, and restricted cash at end of period	$	518	$	520
Note (1) Includes amortization of debt issuance costs and premiums/discounts.
The accompanying notes are an integral part of these consolidated financial statements.

10

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL (Unaudited)

For the Three Months Ended December 31, 2023 and 2022

	Power Program Appropriation Investment		Power Program Retained Earnings		Nonpower Programs Appropriation Investment, Net		Accumulated Other Comprehensive Income (Loss)		Total
Balance at September 30, 2022	$	258	$	14,800	$	533	$	(86)	$	15,505
Net income (loss)	—		103		(2)		—		101
Total other comprehensive income	—		—		—		37		37
Return on power program appropriation investment	—		(1)		—		—		(1)
Balance at December 31, 2022	$	258	$	14,902	$	531	$	(49)	$	15,642
Balance at September 30, 2023	$	258	$	15,302	$	525	$	(29)	$	16,056
Net income (loss)	—		129		(2)		—		127
Total other comprehensive income	—		—		—		1		1
Return on power program appropriation investment	—		(2)		—		—		(2)
Balance at December 31, 2023	$	258	$	15,429	$	523	$	(28)	$	16,182
The accompanying notes are an integral part of these consolidated financial statements.

11

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

(Dollars in millions except where noted)

Note		Page
1	Summary of Significant Accounting Policies	12
2	Impact of New Accounting Standards and Interpretations	14
3	Accounts Receivable, Net	14
4	Inventories, Net	15
5	Other Current Assets	15
6	Plant Closures	15
7	Other Long-Term Assets	16
8	Regulatory Assets and Liabilities	17
9	Variable Interest Entities	17
10	Other Long-Term Liabilities	19
11	Asset Retirement Obligations	20
12	Debt and Other Obligations	21
13	Risk Management Activities and Derivative Transactions	23
14	Fair Value Measurements	28
15	Revenue	34
16	Other Income, Net	36
17	Supplemental Cash Flow Information	37
18	Benefit Plans	37
19	Collaborative Arrangement	37
20	Contingencies and Legal Proceedings	38

1.  Summary of Significant Accounting Policies

Basis of Presentation

The Tennessee Valley Authority ("TVA") prepares its consolidated interim financial statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") for consolidated interim financial information. Accordingly, TVA's consolidated interim financial statements do not include all of the information and notes required by GAAP for annual financial statements. As such, they should be read in conjunction with the audited financial statements for the year ended September 30, 2023, and the notes thereto, which are contained in TVA's Annual Report on Form 10-K for the year ended September 30, 2023 (the "Annual Report"). In the opinion of management, all adjustments (consisting of items of a normal recurring nature) considered necessary for fair presentation are included on the consolidated interim financial statements.

The accompanying consolidated interim financial statements, which have been prepared in accordance with GAAP, include the accounts of TVA and variable interest entities ("VIEs") of which TVA is the primary beneficiary. See Note 9 — Variable Interest Entities. Intercompany balances and transactions have been eliminated in consolidation.

Fiscal Year

TVA's fiscal year ends September 30.  Years (2024, 2023, etc.) refer to TVA's fiscal years unless they are preceded by "CY," in which case the references are to calendar years.

Cash, Cash Equivalents, and Restricted Cash

Cash includes cash on hand, non-interest bearing cash, and deposit accounts. All highly liquid investments with original maturities of three months or less are considered cash equivalents. Cash and cash equivalents that are restricted, as to withdrawal or use under the terms of certain contractual agreements, are recorded in Other long-term assets on the Consolidated Balance Sheets. Restricted cash and cash equivalents include cash held in trusts that are currently restricted for TVA economic development loans and for certain TVA environmental programs in accordance with agreements related to compliance with certain environmental regulations.

12

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported on the Consolidated Balance Sheets and Consolidated Statements of Cash Flows:

Cash, Cash Equivalents, and Restricted Cash (in millions)
	At December 31, 2023		At September 30, 2023
Cash and cash equivalents	$	498	$	501
Restricted cash and cash equivalents included in Other long-term assets	20		20
Total cash, cash equivalents, and restricted cash	$	518	$	521

Allowance for Uncollectible Accounts

TVA recognizes an allowance that reflects the current estimate for credit losses expected to be incurred over the life of the financial assets based on historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amounts. The appropriateness of the allowance is evaluated at the end of each reporting period.

To determine the allowance for trade receivables, TVA considers historical experience and other currently available information, including events such as customer bankruptcy and/or a customer failing to fulfill payment arrangements by the due date. TVA's corporate credit department also performs an assessment of the financial condition of customers and the credit quality of the receivables. In addition, TVA reviews other reasonable and supportable forecasts to determine if the allowance for uncollectible amounts should be further adjusted in accordance with the accounting guidance for Current Expected Credit Losses.

To determine the allowance for loans receivables, TVA aggregates loans into the appropriate pools based on the existence of similar risk characteristics such as collateral types and internal assessed credit risks. In situations where a loan exhibits unique risk characteristics and is no longer expected to experience similar risks to the rest of its pool, the loan will be evaluated separately. TVA derives an annual loss rate based on historical loss and then adjusts the rate to reflect TVA's consideration of available information on current conditions and reasonable and supportable future forecasts. This information may include economic and business conditions, default trends, and other internal and external factors. For periods beyond the reasonable and supportable forecast period, TVA uses the current calculated long-term average historical loss rate for the remaining life of the loan portfolio.

The allowance for uncollectible accounts was less than $1 million at both December 31, 2023, and September 30, 2023, for trade accounts receivable. Additionally, loans receivable of $105 million and $104 million at December 31, 2023, and September 30, 2023, respectively, are included in Accounts receivable, net and Other long-term assets, for the current and long-term portions, respectively. Loans receivables are reported net of allowances for uncollectible accounts of $3 million at both December 31, 2023 and September 30, 2023.

Pre-Commercial Plant Operations

As part of the process of completing the construction of a generating unit, the electricity produced is used to serve the demands of the electric system. TVA estimates revenues earned during pre-commercial operations at the fair value of the energy delivered based on TVA's hourly incremental dispatch cost. Pre-commercial plant operations began on Paradise Combustion Turbine Units 5-7 in the first quarter of 2024, and the units became operational on December 29, 2023. Estimated revenue of $3 million related to this project was capitalized to offset project costs for the three months ended December 31, 2023. TVA also capitalized related fuel costs for this project of $3 million for the three months ended December 31, 2023.

Depreciation    

TVA accounts for depreciation of its properties using the composite depreciation convention of accounting. Under the composite method, assets with similar economic characteristics are grouped and depreciated as one asset. Depreciation is generally computed on a straight-line basis over the estimated service lives of the various classes of assets. The estimation of asset useful lives requires management judgment, supported by external depreciation studies of historical asset retirement experience. Depreciation rates are determined based on external depreciation studies that are updated approximately every five years, with the latest study implemented during the first quarter of 2022. Depreciation expense was $452 million and $466 million for the three months ended December 31, 2023 and 2022, respectively. See Note 6 — Plant Closures for a discussion of the impact of plant closures.

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2.  Impact of New Accounting Standards and Interpretations     

The following are accounting standard updates issued by the Financial Accounting Standards Board that TVA adopted during 2024:

Accounting for Contract Assets and Contract Liabilities from Contracts with Customers
Description	This guidance requires an entity (acquirer) to recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with revenue with customers. It is expected that an acquirer will generally recognize and measure acquired contract assets and contract liabilities in a manner consistent with how the acquiree recognized and measured contract assets and contract liabilities in the acquiree’s financial statements. The entity should apply the standard prospectively to business combinations occurring on or after the effective date of the standard.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

Troubled Debt Restructurings and Vintage Disclosures
Description	This guidance eliminates the recognition and measurement guidance on troubled debt restructuring for creditors that have adopted Financial Instruments-Credit Losses and requires enhanced disclosures about loan modifications for borrowers experiencing financial difficulty. Additionally, the guidance requires public business entities to present current-period gross write-offs by year of origination in their vintage disclosures. The entity should apply the standard prospectively except for the transition method related to the recognition and measurement of troubled debt restructuring. For the transition method, an entity has the option to apply a modified retrospective transition method, resulting in a cumulative-effect adjustment to retained earnings in the period of adoption.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

The following accounting standard has been issued but as of December 31, 2023, was not effective and has not been adopted by TVA:

Improvements to Reportable Segment Disclosures
Description	This guidance improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The amendment requires a public entity to disclose, on an annual and interim basis, significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss. It also requires a public entity that has a single reportable segment to provide all of the disclosures required by the amendment and all existing segment disclosures. The amendment is effective for public entities for fiscal years beginning after December 15, 2023, and interim periods in fiscal years beginning after December 15, 2024. The amendment should be adopted retrospectively unless it is impracticable to do so. Upon adoption, a public entity will adopt the amendment as of the beginning of the earliest period presented.
Effective Date for TVA	October 1, 2024
Effect on the Financial Statements or Other Significant Matters	TVA is currently reviewing and evaluating this standard. TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations, or cash flows.

3.  Accounts Receivable, Net

Accounts receivable primarily consist of amounts due from customers for power sales.  The table below summarizes the types and amounts of TVA's accounts receivable:

Accounts Receivable, Net (in millions)
	At December 31, 2023		At September 30, 2023
Power receivables	$	1,451	$	1,627
Other receivables	142		118
Accounts receivable, net(1)	$	1,593	$	1,745

Note

(1) Allowance for uncollectible accounts was less than $1 million at both December 31, 2023, and September 30, 2023, and therefore is not represented in the table above.

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4.  Inventories, Net

The table below summarizes the types and amounts of TVA's inventories:

Inventories, Net (in millions)
	At December 31, 2023		At September 30, 2023
Materials and supplies inventory	$	884	$	849
Fuel inventory	354		313
Renewable energy certificates/emissions allowance inventory, net	16		15
Allowance for inventory obsolescence	(72)		(69)
Inventories, net	$	1,182	$	1,108

5. Other Current Assets

Other current assets consisted of the following:

Other Current Assets  (in millions)
	At December 31, 2023		At September 30, 2023
Inventory work-in-progress	$	47	$	28
Prepaid software maintenance	36		18
Commodity contract derivative assets	19		21
Prepaid insurance	16		16
Current portion of prepaid long-term service agreements	10		25
Other	24		26
Other current assets	$	152	$	134

Commodity Contract Derivative Assets. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity as well as certain financial derivative contracts to hedge exposure to the price of natural gas. Commodity contract derivative assets classified as current include deliveries or settlements that will occur within 12 months or less. See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.

6. Plant Closures

Background

TVA must continuously evaluate all generating assets to ensure an optimal energy portfolio that provides safe, clean, and reliable power while maintaining flexibility and fiscal responsibility to the people of the Tennessee Valley. Based on results of assessments presented to the TVA Board of Directors ("TVA Board") in 2019, the retirement of Bull Run Fossil Plant ("Bull Run") by December 2023 was approved, and as of September 30, 2023, the facility was retired. In January 2023, TVA issued its Record of Decision to retire the two coal-fired units at Cumberland Fossil Plant ("Cumberland") by the end of CY 2026 and CY 2028. In addition, TVA is evaluating the impact of retiring the balance of the coal-fired fleet by 2035, and that evaluation includes environmental reviews, public input, and TVA Board approval.

Financial Impact

TVA's policy is to adjust depreciation rates to reflect the most current assumptions, ensuring units will be fully depreciated by the applicable retirement dates. As a result of TVA's decision to accelerate the retirement of Bull Run, TVA recognized a cumulative $659 million of accelerated depreciation from the second quarter of 2019 through September 30, 2023. Of this amount, $36 million was recognized for Bull Run during the three months ended December 31, 2022. TVA's decision to retire the two units at Cumberland is estimated to result in approximately $16 million of additional depreciation quarterly, which does not include any potential impact from additions or retirements to net completed plant. TVA estimates it has recognized a cumulative $64 million of additional depreciation since January 2023, related to this decision.

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7.  Other Long-Term Assets

The table below summarizes the types and amounts of TVA's other long-term assets:

Other Long-Term Assets (in millions)
	At December 31, 2023		At September 30, 2023
Loans and other long-term receivables, net	$	101	$	97
EnergyRight® receivables, net	46		47
Prepaid long-term service agreements	44		64
Prepaid capital assets	21		28
Commodity contract derivative assets	12		12
Other	88		82
Total other long-term assets	$	312	$	330

Loans and Other Long-Term Receivables. TVA's loans and other long-term receivables primarily consist of economic development loans for qualifying organizations and a receivable for reimbursements to recover the cost of providing long-term, on-site storage for spent nuclear fuel. The current and long-term portions of the loans receivable are reported in Accounts receivable, net and Other long-term assets, respectively, on TVA's Consolidated Balance Sheets. At December 31, 2023 and September 30, 2023, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $4 million and $7 million, respectively.

EnergyRight® Receivables. In association with the EnergyRight® program, TVA's local power company customers ("LPCs") offer financing to end-use customers for the purchase of energy-efficient equipment. Depending on the nature of the energy-efficiency project, loans may have a maximum term of five years or 10 years. TVA purchases the resulting loans receivable from its LPCs. The loans receivable are then transferred to a third-party bank with which TVA has agreed to repay in full any loans receivable that have been in default for 180 days or more or that TVA has determined are uncollectible. Given this continuing involvement, TVA accounts for the transfer of the loans receivable as secured borrowings. The current and long-term portions of the loans receivable are reported in Accounts receivable, net and Other long-term assets, respectively, on TVA's Consolidated Balance Sheets. At December 31, 2023, and September 30, 2023, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $13 million and $12 million, respectively. See Note 10 — Other Long-Term Liabilities for information regarding the associated financing obligation.

Allowance for Loan Losses. The allowance for loan loss is an estimate of expected credit losses, measured over the estimated life of the loan receivables, that considers reasonable and supportable forecasts of future economic conditions in addition to information about historical experience and current conditions. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts.

The allowance components, which consist of a collective allowance and specific loans allowance, are based on the risk characteristics of TVA's loans. Loans that share similar risk characteristics are evaluated on a collective basis in measuring credit losses, while loans that do not share similar risk characteristics with other loans are evaluated on an individual basis.

Allowance Components (in millions)
	At December 31, 2023		At September 30, 2023
EnergyRight® loan reserve	$	1	$	1
Economic development loan collective reserve	1		1
Economic development loan specific loan reserve	1		1
Total allowance for loan losses	$	3	$	3

Prepaid Long-Term Service Agreements. TVA has entered into various long-term service agreements for major maintenance activities at certain of its combined cycle plants. TVA uses the direct expense method of accounting for these arrangements. TVA accrues for parts when it takes ownership and for contractor services when they are rendered. Under certain of these agreements, payments made exceed the value of parts received and services rendered. The current and long-term portions of the resulting prepayments are reported in Other current assets and Other long-term assets, respectively, on TVA's Consolidated Balance Sheets. At December 31, 2023, and September 30, 2023, prepayments of $10 million and $25 million, respectively, were recorded in Other current assets.

Commodity Contract Derivative Assets. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity as well as certain financial derivative contracts to hedge exposure to the

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price of natural gas. See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.

8.  Regulatory Assets and Liabilities

TVA records certain assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for non-regulated entities. As such, certain items that would generally be reported in earnings or that would impact the Consolidated Statements of Operations are recorded as regulatory assets or regulatory liabilities. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates.  Regulatory liabilities generally represent obligations to make refunds to customers for previous collections for costs that are not likely to be incurred or deferral of gains that will be credited to customers in future periods. Components of regulatory assets and regulatory liabilities are summarized in the table below.

Regulatory Assets and Liabilities (in millions)
	At December 31, 2023		At September 30, 2023
Current regulatory assets
Unrealized losses on interest rate derivatives	$	37	$	31
Unrealized losses on commodity derivatives	213		136
Fuel cost adjustment receivable	—		11
Other current regulatory assets	1		—
Total current regulatory assets	251		178
Non-current regulatory assets
Retirement benefit plans deferred costs	1,438		1,440
Non-nuclear decommissioning costs	2,838		2,922
Unrealized losses on interest rate derivatives	459		272
Nuclear decommissioning costs	543		728
Unrealized losses on commodity derivatives	98		52
Other non-current regulatory assets	175		152
Total non-current regulatory assets	5,551		5,566
Total regulatory assets	$	5,802	$	5,744
Current regulatory liabilities
Fuel cost adjustment tax equivalents	$	190	$	201
Fuel cost adjustment	50		—
Unrealized gains on commodity derivatives	19		21
Total current regulatory liabilities	259		222
Non-current regulatory liabilities
Retirement benefit plans deferred credits	91		95
Unrealized gains on commodity derivatives	12		12
Total non-current regulatory liabilities	103		107
Total regulatory liabilities	$	362	$	329

9.  Variable Interest Entities

A VIE is an entity that either (i) has insufficient equity to permit the entity to finance its activities without additional subordinated financial support or (ii) has equity investors who lack the characteristics of owning a controlling financial interest. When TVA determines that it has a variable interest in a VIE, a qualitative evaluation is performed to assess which interest holders have the power to direct the activities that most significantly impact the economic performance of the entity and have the obligation to absorb losses or receive benefits that could be significant to the entity. The evaluation considers the purpose and

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design of the business, the risks that the business was designed to create and pass along to other entities, the activities of the business that can be directed and which party can direct them, and the expected relative impact of those activities on the economic performance of the business through its life. TVA has the power to direct the activities of an entity when it has the ability to make key operating and financing decisions, including, but not limited to, capital investment and the issuance of debt. Based on the evaluation of these criteria, TVA has determined it is the primary beneficiary of certain entities and as such is required to account for the VIEs on a consolidated basis.

John Sevier VIEs

In 2012, TVA entered into a $1.0 billion construction management agreement and lease financing arrangement with John Sevier Combined Cycle Generation LLC ("JSCCG") for the completion and lease by TVA of the John Sevier Combined Cycle Facility ("John Sevier CCF"). JSCCG is a special single-purpose limited liability company formed in January 2012 to finance the John Sevier CCF through a $900 million secured note issuance (the "JSCCG notes") and the issuance of $100 million of membership interests subject to mandatory redemption.  The membership interests were purchased by John Sevier Holdco LLC ("Holdco").  Holdco is a special single-purpose entity, also formed in January 2012, established to acquire and hold the membership interests in JSCCG.  A non-controlling interest in Holdco is held by a third party through nominal membership interests, to which none of the income, expenses, and cash flows are allocated. 

The membership interests held by Holdco in JSCCG were purchased with proceeds from the issuance of $100 million of secured notes (the "Holdco notes") and are subject to mandatory redemption pursuant to a schedule of amortizing, semi-annual payments due each January 15 and July 15, with a final payment due in January 2042. The payment dates for the mandatorily redeemable membership interests are the same as those of the Holdco notes. The sale of the JSCCG notes, the membership interests in JSCCG, and the Holdco notes closed in January 2012. The JSCCG notes are secured by TVA's lease payments, and the Holdco notes are secured by Holdco's investment in, and amounts receivable from, JSCCG. TVA's lease payments to JSCCG are equal to and payable on the same dates as JSCCG's and Holdco's semi-annual debt service payments. In addition to the lease payments, TVA pays administrative and miscellaneous expenses incurred by JSCCG and Holdco. Certain agreements related to this transaction contain default and acceleration provisions.

Due to its participation in the design, business activity, and credit and financial support of JSCCG and Holdco, TVA has determined that it has a variable interest in each of these entities. Based on its analysis, TVA has concluded that it is the primary beneficiary of JSCCG and Holdco and, as such, is required to account for the VIEs on a consolidated basis. Holdco's membership interests in JSCCG are eliminated in consolidation.

Southaven VIE

In 2013, TVA entered into a $400 million lease financing arrangement with Southaven Combined Cycle Generation LLC ("SCCG") for the lease by TVA of the Southaven Combined Cycle Facility ("Southaven CCF"). SCCG is a special single-purpose limited liability company formed in June 2013 to finance the Southaven CCF through a $360 million secured notes issuance (the "SCCG notes") and the issuance of $40 million of membership interests subject to mandatory redemption. The membership interests were purchased by Southaven Holdco LLC ("SHLLC"). SHLLC is a special single-purpose entity, also formed in June 2013, established to acquire and hold the membership interests in SCCG. A non-controlling interest in SHLLC is held by a third party through nominal membership interests, to which none of the income, expenses, and cash flows of SHLLC are allocated.

The membership interests held by SHLLC were purchased with proceeds from the issuance of $40 million of secured notes (the "SHLLC notes") and are subject to mandatory redemption pursuant to a schedule of amortizing, semi-annual payments due each February 15 and August 15, with a final payment due on August 15, 2033. The payment dates for the mandatorily redeemable membership interests are the same as those of the SHLLC notes, and the payment amounts are sufficient to provide returns on, as well as returns of, capital until the investment has been repaid to SHLLC in full. The rate of return on investment to SHLLC is seven percent, which is reflected as interest expense in the Consolidated Statements of Operations. SHLLC is required to pay a pre-determined portion of the return on investment to Seven States Southaven, LLC on each lease payment date as agreed in SHLLC's formation documents (the "Seven States Return"). The current and long-term portions of the Membership interests of VIE subject to mandatory redemption are included in Accounts payable and accrued liabilities and Other long-term liabilities, respectively.

The payment dates for the mandatorily redeemable membership interests are the same as those of the SHLLC notes. The SCCG notes are secured by TVA's lease payments, and the SHLLC notes are secured by SHLLC's investment in, and amounts receivable from, SCCG. TVA's lease payments to SCCG are payable on the same dates as SCCG's and SHLLC's semi-annual debt service payments and are equal to the sum of (i) the amount of SCCG's semi-annual debt service payments, (ii) the amount of SHLLC's semi-annual debt service payments, and (iii) the amount of the Seven States Return. In addition to the lease payments, TVA pays administrative and miscellaneous expenses incurred by SCCG and SHLLC. Certain agreements related to this transaction contain default and acceleration provisions.

In the event that TVA were to choose to exercise an early buy out feature of the Southaven facility lease, in part or in whole, TVA must pay to SCCG amounts sufficient for SCCG to repay or partially repay on a pro rata basis the membership interests held by SHLLC, including any outstanding investment amount plus accrued but unpaid return. TVA also has the right, at

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any time and without any early redemption of the other portions of the Southaven facility lease payments due to SCCG, to fully repay SHLLC's investment, upon which repayment SHLLC will transfer the membership interests to a designee of TVA.

TVA participated in the design, business activity, and financial support of SCCG and has determined that it has a direct variable interest in SCCG resulting from risk associated with the value of the Southaven CCF at the end of the lease term. Based on its analysis, TVA has determined that it is the primary beneficiary of SCCG and, as such, is required to account for the VIE on a consolidated basis.

Impact on Consolidated Financial Statements

The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG at December 31, 2023, and September 30, 2023, as reflected on the Consolidated Balance Sheets, are as follows:

Summary of Impact of VIEs on Consolidated Balance Sheets (in millions)
	At December 31, 2023		At September 30, 2023
Current liabilities
Accrued interest	$	21	$	9
Accounts payable and accrued liabilities	1		1
Current maturities of long-term debt of variable interest entities	35		35
Total current liabilities	57		45
Other liabilities
Other long-term liabilities	17		17
Long-term debt, net
Long-term debt of variable interest entities, net	933		933
Total liabilities	$	1,007	$	995

Interest expense of $12 million for both the three months ended December 31, 2023 and 2022, is included in the Consolidated Statements of Operations related to debt of VIEs and membership interests of VIEs subject to mandatory redemption.

Creditors of the VIEs do not have any recourse to the general credit of TVA. TVA does not have any obligations to provide financial support to the VIEs other than as prescribed in the terms of the agreements related to these transactions.

10.  Other Long-Term Liabilities

Other long-term liabilities consist primarily of liabilities related to certain derivative agreements as well as liabilities related to operating leases. The table below summarizes the types and amounts of Other long-term liabilities:

Other Long-Term Liabilities (in millions)
	At December 31, 2023		At September 30, 2023
Interest rate swap liabilities	$	782	$	627
Operating lease liabilities	163		93
Currency swap liabilities	112		131
Commodity contract derivative liabilities	98		52
EnergyRight® financing obligation	55		55
Advances for construction	46		56
Long-term deferred revenue	46		45
Long-term deferred compensation	32		41
Other	154		111
Total other long-term liabilities	$	1,488	$	1,211

Interest Rate Swap Liabilities. TVA uses interest rate swaps to fix variable short-term debt to a fixed rate. The values of these derivatives are included in Other current assets, Accounts payable and accrued liabilities, Accrued interest, and Other long-term liabilities on the Consolidated Balance Sheets. See Note 13 — Risk Management Activities and Derivative

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Transactions — Overview of Accounting Treatment and Derivatives Not Receiving Hedge Accounting Treatment — Interest Rate Derivatives for information regarding the interest rate swap liabilities.

Operating Lease Liabilities. TVA's operating leases consist primarily of railcars, equipment, real estate/land, and power generating facilities. At December 31, 2023, and September 30, 2023, the current portion of TVA's operating leases reported in Accounts payable and accrued liabilities was $81 million and $71 million, respectively.

Currency Swap Liabilities. To protect against exchange rate risk related to British pound sterling denominated Bond transactions, TVA entered into foreign currency hedges. The values of these derivatives are included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. See Note 13 — Risk Management Activities and Derivative Transactions — Overview of Accounting Treatment and Cash Flow Hedging Strategy for Currency Swaps for more information regarding the currency swap liabilities.

Commodity Contract Derivative Liabilities. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity as well as certain financial derivative contracts to hedge exposure to the price of natural gas. See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.

EnergyRight® Financing Obligation. TVA purchases certain loans receivable from its LPCs in association with the EnergyRight® program. The current and long-term portions of the resulting financing obligation are reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA's Consolidated Balance Sheets. At both December 31, 2023, and September 30, 2023, the carrying amount of the financing obligation reported in Accounts payable and accrued liabilities was $14 million. See Note 7 — Other Long-Term Assets for information regarding the associated loans receivable.

Long-Term Deferred Compensation. TVA provides compensation arrangements to engage and retain certain employees, both executive and non-executive, which are designed to provide participants with the ability to defer compensation to future periods. The current and long-term portions are recorded in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA’s Consolidated Balance Sheets. At December 31, 2023 and September 30, 2023, the current amount of deferred compensation recorded in Accounts payable and accrued liabilities was $32 million and $65 million, respectively.

Advances for Construction. TVA receives refundable and non-refundable advances for construction that are generally intended to defray all or a portion of the costs of building or extending TVA’s existing power assets. Amounts received are deferred as a liability with the long-term portion representing amounts that will not be recognized within the next 12 months. As projects meet milestones or other contractual obligations, the refundable portion is refunded to the customer and the non-refundable portion is recognized as contributions in aid of construction and offsets the cost of plant assets. At December 31, 2023 and September 30, 2023, the current amount of advances for construction recorded in Accounts payable and accrued liabilities was $60 million and $39 million, respectively.

Long-Term Deferred Revenue. Long-term deferred revenue represents payments received that exceed services rendered resulting in the deferral of revenue. The long-term portion represents amounts that will not be recognized within the next 12 months primarily related to fiber and transmission agreements. The current and long-term portions of the deferral are reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA’s Consolidated Balance Sheets. At December 31, 2023 and September 30, 2023, the current amount of deferred revenue recorded in Accounts payable and accrued liabilities was $23 million and $21 million, respectively.

11.  Asset Retirement Obligations

During the three months ended December 31, 2023, TVA's total asset retirement obligations ("ARO") liability increased $81 million as a result of revisions in estimate and periodic accretion, partially offset by settlements related to retirement projects that were conducted during the period. The nuclear and non-nuclear accretion amounts were deferred as regulatory assets.  During the three months ended December 31, 2023, $47 million of the related regulatory assets were amortized into expense as these amounts were collected in rates. See Note 8 — Regulatory Assets and Liabilities. TVA maintains investment trusts to help fund its decommissioning obligations. See Note 14 — Fair Value Measurements — Investment Funds and Note 20 — Contingencies and Legal Proceedings — Contingencies — Decommissioning Costs for a discussion of the trusts' objectives and the current balances of the trusts.

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Asset Retirement Obligation Activity (in millions)
	Nuclear		Non-Nuclear		Total
Balance at September 30, 2023	$	3,808	$	3,681	$	7,489	(1)
Settlements	(4)		(59)		(63)
Revisions in estimate	—		78		78
Accretion (recorded as regulatory asset)	43		23		66
Balance at December 31, 2023	$	3,847	$	3,723	$	7,570	(1)

Note

(1) Includes $275 million and $272 million at December 31, 2023, and September 30, 2023, respectively, in Current liabilities.

Revisions to non-nuclear estimates increased the liability balance by $78 million for the three months ended December 31, 2023. The increase was primarily attributable to a change in closure liabilities of $76 million at Cumberland based on scope changes to the interim closure plan and updated cost estimates for activities associated with final closure.

12.  Debt and Other Obligations

Debt Outstanding

Total debt outstanding at December 31, 2023, and September 30, 2023, consisted of the following:

Debt Outstanding  (in millions)
	At December 31, 2023		At September 30, 2023
Short-term debt
Short-term debt, net of discounts	$	1,042	$	432
Current maturities of power bonds issued at par	1,022		1,022
Current maturities of long-term debt of VIEs issued at par	35		35
Total current debt outstanding, net	2,099		1,489
Long-term debt
Long-term power bonds(1)	17,990		17,970
Long-term debt of VIEs, net	933		933
Unamortized discounts, premiums, issue costs, and other	(123)		(126)
Total long-term debt, net	18,800		18,777
Total debt outstanding	$	20,899	$	20,266

Note

(1) Includes total net exchange gain from currency transactions of $88 million and $109 million at December 31, 2023, and September 30, 2023, respectively.

Debt Securities Activity

The table below summarizes the long-term debt securities activity for the period from October 1, 2023, to December 31, 2023:

Debt Securities Activity
	Date	Amount (in millions)
Redemptions/Maturities(1)
2009 Series B	December 2023	$	1
Total redemptions/maturities of debt		$	1

Note

(1) All redemptions were at 100 percent of par.

Credit Facility Agreements

TVA has funding available under four long-term revolving credit facilities totaling $2.7 billion. See the table below for additional information on the four long-term revolving credit facilities. The interest rate on any borrowing under these facilities varies based on market factors and the rating of TVA's senior unsecured, long-term, non-credit-enhanced debt. TVA is required to pay an unused facility fee on the portion of the total $2.7 billion that TVA has not borrowed or committed under letters of credit.

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This fee, along with letter of credit fees, may fluctuate depending on the rating of TVA's senior unsecured, long-term, non-credit-enhanced debt. At December 31, 2023, and September 30, 2023, there were $469 million and $535 million, respectively, of letters of credit outstanding under these facilities, and there were no borrowings outstanding. TVA's letters of credit are primarily posted as collateral under TVA's interest rate swaps. See Note 13 — Risk Management Activities and Derivative Transactions — Other Derivative Instruments — Collateral. TVA may also post collateral for TVA's currency swaps, for commodity derivatives under the Financial Hedging Program ("FHP"), or for certain transactions with third parties that require TVA to post letters of credit.

The following table provides additional information regarding TVA's funding available under the four long-term revolving credit facilities:

Summary of Long-Term Credit Facilities At December 31, 2023 (in millions)
Maturity Date	Facility Limit		Letters of Credit Outstanding		Cash Borrowings		Availability
February 2025	$	500	$	223	$	—	$	277
March 2026	150		38		—		112
September 2026	1,000		112		—		888
March 2027	1,000		96		—		904
Total	$	2,650	$	469	$	—	$	2,181

TVA and the United States ("U.S.") Department of the Treasury ("U.S. Treasury"), pursuant to the Tennessee Valley Authority Act of 1933, as amended ("TVA Act"), have entered into a memorandum of understanding under which the U.S. Treasury provides TVA with a $150 million credit facility. This credit facility was renewed for 2024 with a maturity date of September 30, 2024. Access to this credit facility or other similar financing arrangements with the U.S. Treasury has been available to TVA since the 1960s. TVA can borrow under the U.S. Treasury credit facility only if it cannot issue bonds, notes, or other evidences of indebtedness (collectively, "Bonds") in the market on reasonable terms, and TVA considers the U.S. Treasury credit facility a secondary source of liquidity. The interest rate on any borrowing under this facility is based on the average rate on outstanding marketable obligations of the U.S. with maturities from date of issue of 12 months or less. There were no outstanding borrowings under the facility at December 31, 2023. The availability of this credit facility may be impacted by how the U.S. government addresses the possibility of approaching its debt limit.

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13.  Risk Management Activities and Derivative Transactions

TVA is exposed to various risks related to commodity prices, investment prices, interest rates, currency exchange rates, and inflation as well as counterparty credit and performance risks.  To help manage certain of these risks, TVA has historically entered into various derivative transactions, principally commodity option contracts, forward contracts, swaps, swaptions, futures, and options on futures.  

Overview of Accounting Treatment

TVA recognizes certain of its derivative instruments as either assets or liabilities on its Consolidated Balance Sheets at fair value.  The accounting for changes in the fair value of these instruments depends on (1) whether TVA uses regulatory accounting to defer the derivative gains and losses, (2) whether the derivative instrument has been designated and qualifies for hedge accounting treatment, and (3) if so, the type of hedge relationship (for example, cash flow hedge).

The following tables summarize the accounting treatment that certain of TVA's financial derivative transactions receive:

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 1)  Amount of Mark-to-Market Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) (in millions)
			Three Months Ended December 31
Derivatives in Cash Flow Hedging Relationship	Objective of Hedge Transaction	Accounting for Derivative Hedging Instrument	2023		2022
Currency swaps	To protect against changes in cash flows caused by changes in foreign currency exchange rates (exchange rate risk)	Unrealized gains and losses are recorded in AOCI and reclassified to Interest expense to the extent they are offset by gains and losses on the hedged transaction	$	20	$	71

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2)(1) Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Interest Expense (in millions)
	Three Months Ended December 31
Derivatives in Cash Flow Hedging Relationship	2023		2022
Currency swaps	$	19	$	34

Note

(1) There were no amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $3 million of gains from Accumulated other comprehensive income (loss) ("AOCI") to Interest expense within the next 12 months to offset amounts anticipated to be recorded in Interest expense related to the forecasted exchange loss on the debt.

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment Amount of Gain (Loss) Recognized in Income on Derivatives(1) (in millions)
			Three Months Ended December 31
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2023		2022
Interest rate swaps	To fix short-term debt variable rate to a fixed rate (interest rate risk)	Mark-to-market gains and losses are recorded as regulatory liabilities and assets, respectively Realized gains and losses are recognized in Interest expense when incurred during the settlement period and are presented in operating cash flow	$	(8)	$	(15)
Commodity derivatives under the FHP	To protect against fluctuations in market prices of purchased commodities (price risk)	Mark-to-market gains and losses are recorded as regulatory liabilities and assets, respectively Realized gains and losses are recognized in Fuel expense or Purchased power expense as the contracts settle to match the delivery period of the underlying commodity(2)	(54)		(19)

Notes

(1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the three months ended December 31, 2023 and for the three months ended December 31, 2022.

(2) Of the amount recognized for the three months ended December 31, 2023, $44 million and $10 million were reported in Fuel expense and Purchased power expense, respectively. Of the amount recognized for three months ended December 31, 2022, $15 million and $4 million were reported in Fuel expense and Purchased power expense, respectively.

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Fair Values of TVA Derivatives (in millions)
	At December 31, 2023			At September 30, 2023
Derivatives That Receive Hedge Accounting Treatment:
	Balance		Balance Sheet Presentation	Balance		Balance Sheet Presentation
Currency swaps
£250 million Sterling	$	(56)	Accounts payable and accrued liabilities $(5); Other long-term liabilities $(51)	$	(72)	Accounts payable and accrued liabilities $(6); Other long-term liabilities $(66)
£150 million Sterling	(65)		Accounts payable and accrued liabilities $(4); Other long-term liabilities $(61)	(69)		Accounts payable and accrued liabilities $(4); Other long-term liabilities $(65)
Derivatives That Do Not Receive Hedge Accounting Treatment:
	Balance		Balance Sheet Presentation	Balance		Balance Sheet Presentation
Interest rate swaps
$1.0 billion notional	$	(607)	Accounts payable and accrued liabilities $(22); Accrued interest $(6); Other long-term liabilities $(579)	$	(499)	Other current assets $1; Accrued interest $(27); Other long-term liabilities $(473)
$476 million notional	(211)		Accounts payable and accrued liabilities $(8); Other long-term liabilities $(203)	(159)		Other current assets $3; Accrued interest $(8); Other long-term liabilities $(154)
Commodity contract derivatives	29		Other current assets $19; Other long-term assets $12; Accounts payable and accrued liabilities $(1); Other long-term liabilities $(1)	31		Other current assets $21; Other long-term assets $12; Accounts payable and accrued liabilities $(1); Other long-term liabilities $(1)
Commodity derivatives under the FHP	(309)		Accounts payable and accrued liabilities $(212); Other long-term liabilities $(97)	(186)		Accounts payable and accrued liabilities $(135); Other long-term liabilities $(51)

Cash Flow Hedging Strategy for Currency Swaps

To protect against exchange rate risk related to British pound sterling denominated Bond transactions, TVA entered into foreign currency hedges at the time the Bond transactions occurred.  TVA had two currency swaps outstanding at December 31, 2023, with total currency exposure of £400 million and expiration dates in 2032 and 2043.

When the dollar strengthens against the British pound sterling, the exchange gain on the Bond liability and related accrued interest is offset by an equal amount of loss on the swap contract that is reclassified out of AOCI. Conversely, the exchange loss on the Bond liability and related accrued interest is offset by an equal amount of gain on the swap contract that is reclassified out of AOCI. All such exchange gains or losses on the Bond liability and related accrued interest are included in Long-term debt, net and Accrued interest, respectively. The offsetting exchange losses or gains on the swap contracts are recognized in AOCI. If any gain (loss) were to be incurred as a result of the early termination of the foreign currency swap contract, the resulting income (expense) would be amortized over the remaining life of the associated Bond as a component of Interest expense. The values of the currency swap liabilities are included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets.

Derivatives Not Receiving Hedge Accounting Treatment

Interest Rate Derivatives.  Generally TVA uses interest rate swaps to fix variable short-term debt to a fixed rate, and TVA uses regulatory accounting treatment to defer the mark-to-market ("MtM") gains and losses on its interest rate swaps. The net deferred unrealized gains and losses are classified as regulatory liabilities or assets on TVA's Consolidated Balance Sheets and are included in the ratemaking formula when gains or losses are realized. The values of these derivatives are included in Other current assets, Accounts payable and accrued liabilities, Accrued interest, and Other long-term liabilities on the Consolidated Balance Sheets, and realized gains and losses, if any, are included on TVA's Consolidated Statements of Operations. For the three months ended December 31, 2023 and 2022, the changes in fair market value of the interest rate swaps resulted in the increase in unrealized losses of $189 million and reduction in unrealized losses of $14 million, respectively. TVA may hold short-term debt balances lower than the notional amount of the interest rate swaps from time to time due to changes in business conditions and other factors. While actual balances vary, TVA generally plans to maintain average balances of short-term debt equal to or in excess of the combined notional amount of the interest rate swaps.

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Commodity Derivatives. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity. TVA may also enter into short-term power purchase agreements ("PPAs") with a term of less than one year that provide an option to financially settle contracted power deliveries. This option creates an embedded derivative in the hosting PPA. TVA marks to market these contracts and defers the unrealized gains (losses) as regulatory liabilities (assets). At December 31, 2023, TVA's natural gas contract derivatives had terms of up to approximately two years.

Commodity Contract Derivatives
	At December 31, 2023				At September 30, 2023
	Number of Contracts	Notional Amount	Fair Value (MtM) (in millions)		Number of Contracts	Notional Amount	Fair Value (MtM) (in millions)
Natural gas contract derivatives	45	366 million mmBtu	$	29	54	318 million mmBtu	$	31

Commodity Derivatives under the FHP. Currently, TVA is hedging exposure to the price of natural gas under the FHP. There is no Value at Risk aggregate transaction limit under the current FHP structure, but the TVA Board reviews and authorizes the use of tolerances and measures annually. TVA's FHP policy prohibits trading financial instruments under the FHP for speculative purposes. At December 31, 2023, TVA's natural gas swap contracts under the FHP had remaining terms of up to approximately four years.

Commodity Derivatives under Financial Hedging Program(1)
	At December 31, 2023					At September 30, 2023
	Number of Contracts	Notional Amount		Fair Value (MtM) (in millions)		Number of Contracts	Notional Amount		Fair Value (MtM) (in millions)
Natural gas
Swap contracts	206	351	million mmBtu	$	(309)	221	388	million mmBtu	$	(186)

Note

(1) Fair value amounts presented are based on the net commodity position with the counterparty. Notional amounts disclosed represent the net value of contractual amounts.

TVA defers all FHP unrealized gains (losses) as regulatory liabilities (assets) and records the realized gains or losses in Fuel expense and Purchased power expense to match the delivery period of the underlying commodity. The fair value of commodity derivatives under the FHP decreased $123 million primarily due to a decrease in forward natural gas prices at December 31, 2023 as compared to September 30, 2023.

Offsetting of Derivative Assets and Liabilities

The amounts of TVA's derivative instruments as reported on the Consolidated Balance Sheets are shown in the table below:

Derivative Assets and Liabilities(1) (in millions)
	At December 31, 2023		At September 30, 2023
Assets
Commodity contract derivatives	$	31	$	33
Interest rate swaps	—		4
Total derivatives subject to master netting or similar arrangement	$	31	$	37
Liabilities
Currency swaps	$	121	$	141
Interest rate swaps(2)	818		662
Commodity contract derivatives	2		2
Commodity derivatives under the FHP(3)	309		186
Total derivatives subject to master netting or similar arrangement	$	1,250	$	991

Notes

(1) Offsetting amounts include counterparty netting of derivative contracts. Except as discussed below, there were no other material offsetting amounts on TVA's Consolidated Balance Sheets at either December 31, 2023, or September 30, 2023.

(2) Letters of credit of $443 million and $509 million were posted as collateral at December 31, 2023, and September 30, 2023, respectively, to partially secure the

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liability positions of one of the interest rate swaps in accordance with the collateral requirements for this derivative.

(3) At December 31, 2023, the gross derivative asset and gross derivative liability were $8 million and $317 million, respectively, with offsetting amounts for each totaling $8 million.

Other Derivative Instruments

Investment Fund Derivatives.  Investment funds consist primarily of funds held in the Nuclear Decommissioning Trust ("NDT"), the Asset Retirement Trust ("ART"), the Supplemental Executive Retirement Plan ("SERP"), the TVA Deferred Compensation Plan ("DCP"), and the Restoration Plan ("RP"). See Note 14 — Fair Value Measurements — Investment Funds for a discussion of the trusts, plans, and types of investments. The NDT and ART may invest in derivative instruments which may include swaps, futures, options, forwards, and other instruments. At December 31, 2023, and September 30, 2023, the NDT held investments in forward contracts to purchase debt securities. The fair values of these derivatives were in net asset positions totaling $3 million and $11 million at December 31, 2023, and September 30, 2023, respectively.

Collateral.  TVA's interest rate swaps, currency swaps, and commodity derivatives under the FHP contain contract provisions that require a party to post collateral (in a form such as cash or a letter of credit) when the party's liability balance under the agreement exceeds a certain threshold.  At December 31, 2023, the aggregate fair value of all derivative instruments with credit-risk related contingent features that were in a liability position was $1.3 billion.  TVA's collateral obligations at December 31, 2023, under these arrangements were $537 million, for which TVA had posted $443 million in letters of credit. These letters of credit reduce the available balance under the related credit facilities.  TVA's assessment of the risk of its nonperformance includes a reduction in its exposure under the interest rate swap contracts as a result of this posted collateral.

For all of its derivative instruments with credit-risk related contingent features:

•If TVA remains a majority-owned U.S. government entity but Standard & Poor's Financial Services, LLC or Moody's Investors Service, Inc. ("Moody's") downgrades TVA's credit rating to AA or Aa2, respectively, TVA's collateral obligations would likely increase by $22 million, and

•If TVA ceases to be majority-owned by the U.S. government, TVA's credit rating would likely be downgraded and TVA would be required to post additional collateral.

Counterparty Risk

TVA may be exposed to certain risks when a counterparty has the potential to fail to meet its obligations in accordance with agreed terms. These risks may be related to credit, operational, or nonperformance matters. To mitigate certain counterparty risk, TVA analyzes the counterparty's financial condition prior to entering into an agreement, establishes credit limits, monitors the appropriateness of those limits, as well as any changes in the creditworthiness of the counterparty, on an ongoing basis, and when required, employs credit mitigation measures, such as collateral or prepayment arrangements and master purchase and sale agreements.

Customers.  TVA is exposed to counterparty credit risk associated with trade accounts receivable from delivered power sales to LPCs, and from industries and federal agencies directly served, all located in the Tennessee Valley region. Of the $1.5 billion and $1.6 billion of receivables from power sales outstanding at December 31, 2023, and September 30, 2023, respectively, nearly all of the counterparties were rated investment grade. The obligations of these customers that are not investment grade are secured by collateral. TVA is also exposed to risk from exchange power arrangements with a small number of investor-owned regional utilities related to delivered power. TVA believes its policies and procedures for counterparty performance risk reviews have generally protected TVA against significant exposure related to market and economic conditions. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts, Note 3 — Accounts Receivable, Net, and Note 7 — Other Long-Term Assets.

TVA had revenue from two LPCs that collectively accounted for 16 percent of total operating revenues for both the three months ended December 31, 2023 and the three months ended December 31, 2022.

Suppliers.  TVA assesses potential supplier performance risks, including procurement of fuel, purchased power, parts, and services. If suppliers are unable to perform under TVA's existing contracts or if TVA is unable to obtain similar services or supplies from other vendors, TVA could experience delays, disruptions, additional costs, or other operational outcomes that may impact generation, maintenance, and capital programs. If certain fuel or purchased power suppliers fail to perform under the terms of their contract with TVA, TVA might lose the money that it paid to the supplier under the contract and have to purchase replacement fuel or power on the spot market, perhaps at a significantly higher price than TVA was entitled to pay under the contract. In addition, TVA might not be able to acquire replacement fuel or power in a timely manner and thus might be unable to satisfy its own obligations to deliver power. TVA continues evaluating potential supplier performance risks and supplier impact but cannot determine or predict the duration of such risks/impacts or the extent to which such risks/impacts could affect TVA's business, operations, and financial results or cause potential business disruptions.

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TVA continues to experience impacts due to inflation, supply chain material challenges, and labor availability. This has led to project delays and limited availability and/or price increases for supplies and labor. TVA has been able to manage these challenges with limited business disruptions at this time; however, should pressures continue long term, TVA could experience more significant disruptions and pressure to further increase power rates.

Natural Gas and Fuel Oil. TVA purchases a significant amount of its natural gas requirements through contracts with a variety of suppliers and purchases substantially all of its fuel oil requirements on the spot market. TVA delivers to its gas fleet under firm and non-firm transportation contracts on multiple interstate natural gas pipelines. TVA contracts for storage capacity that allows for operational flexibility and increased supply during peak gas demand scenarios or supply disruptions. TVA plans to continue using contracts of various lengths and terms to meet the projected natural gas needs of its natural gas fleet. TVA also maintains on-site, fuel oil backup to operate at the majority of the combustion turbine sites in the event of major supply disruptions. In the event a supplier experiences an incident that limits its ability to fulfill its firm contractual obligations to supply TVA natural gas, TVA will leverage its storage and balancing services and/or replace the volume with a third party to ensure reliability of generation.

Coal. To help ensure a reliable supply of coal, TVA had coal contracts with multiple suppliers at December 31, 2023. The contracted supply of coal is sourced from several geographic regions of the U.S. and is delivered via barge and rail. As a result of emerging technologies, environmental regulations, industry trends, and natural gas market volatility over the past few years, coal suppliers are facing increased financial pressure, which has led to relatively poor credit ratings and bankruptcies, restructuring, mine closures, or other scenarios. A long-term continued decline in demand for coal could result in more consolidations, additional bankruptcies, restructuring, mine closures, or other scenarios.

Nuclear Fuel. Nuclear fuel is obtained predominantly through long-term uranium concentrate supply contracts, contracted conversion services, contracted enrichment services, or a combination thereof, and contracted fuel fabrication services. The supply markets for uranium concentrates and certain nuclear fuel services are subject to price fluctuations and availability restrictions. Supply market conditions may make procurement contracts subject to credit risk related to the potential nonperformance of counterparties. In the event of nonperformance by these or other suppliers, TVA believes that replacement uranium concentrate and nuclear fuel services can be obtained, although at prices that may be unfavorable when compared to the prices under the current supply agreements.

As a result of Russia’s invasion of Ukraine, new contracts for Russian origin nuclear fuel have been limited by Executive Order ("EO") 14066, and further restrictions on the purchase or use of Russian origin fuel may be forthcoming. TVA should have no direct impact from existing or future restrictions since TVA has no Russian origin nuclear fuel in inventory for use in its reactors and it is not contracted to purchase any Russian origin nuclear fuel. TVA could be impacted by higher market prices as a result of general market impacts associated with supply restrictions; however, at this time TVA's nuclear fuel is obtained predominantly through long-term contracts.

Purchased Power. TVA acquires power from a variety of power producers through long-term and short-term PPAs as well as through spot market purchases. Because of the reliability risk of purchased power, TVA requires that the PPAs contain certain counterparty performance assurance requirements to help insure counterparty performance during the term of the agreements.

Other Suppliers. Mounting solar supply chain constraints, commodity price increases, and the recent trade policy investigation into solar panel imports have created challenges for the U.S. solar industry. TVA's Self-Directed Solar project and TVA's existing solar PPA portfolio are not immune from these challenges. Similar to the experience of the rest of the industry, the majority of TVA's contracted PPAs from previous requests for proposals ("RFPs") that are not yet online have been impacted by project delays and price increases, and TVA terminated one PPA because of counterparty default.

Derivative Counterparties.  TVA has entered into physical and financial contracts that are classified as derivatives for hedging purposes, and TVA's NDT, ART, and qualified defined benefit plan ("pension plan") have entered into derivative contracts for investment purposes. If a counterparty to one of the physical or financial derivative transactions defaults, TVA might incur costs in connection with entering into a replacement transaction. If a counterparty to the derivative contracts into which the NDT, the ART, or the pension plan have entered for investment purposes defaults, the value of the investment could decline significantly or perhaps become worthless. TVA has concentrations of credit risk from the banking, coal, and gas industries because multiple companies in these industries serve as counterparties to TVA in various derivative transactions. At December 31, 2023, all of TVA's commodity derivatives under the FHP, currency swaps, and interest rate swaps were with counterparties whose Moody's credit ratings were A2 or higher. TVA classifies forward natural gas contracts as derivatives. At December 31, 2023, the forward natural gas contracts were with counterparties whose ratings ranged from B1 to A1.

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14.  Fair Value Measurements

Fair value is determined based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the asset or liability's principal market, or in the absence of a principal market, the most advantageous market for the asset or liability in an orderly transaction between market participants. TVA uses market or observable inputs as the preferred source of values, followed by assumptions based on hypothetical transactions in the absence of market inputs.

Valuation Techniques

The measurement of fair value results in classification into a hierarchy by the inputs used to determine the fair value as follows:

Level 1	—	Unadjusted quoted prices in active markets accessible by the reporting entity for identical assets or liabilities.  Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing.
Level 2	—	Pricing inputs other than quoted market prices included in Level 1 that are based on observable market data and that are directly or indirectly observable for substantially the full term of the asset or liability.  These include quoted market prices for similar assets or liabilities, quoted market prices for identical or similar assets in markets that are not active, adjusted quoted market prices, inputs from observable data such as interest rate and yield curves, volatilities and default rates observable at commonly quoted intervals, and inputs derived from observable market data by correlation or other means.
Level 3	—	Pricing inputs that are unobservable, or less observable, from objective sources.  Unobservable inputs are only to be used to the extent observable inputs are not available.  These inputs maintain the concept of an exit price from the perspective of a market participant and should reflect assumptions of other market participants.  An entity should consider all market participant assumptions that are available without unreasonable cost and effort.  These are given the lowest priority and are generally used in internally developed methodologies to generate management's best estimate of the fair value when no observable market data is available.

A financial instrument's level within the fair value hierarchy (where Level 1 is the highest and Level 3 is the lowest) is based on the lowest level of input significant to the fair value measurement.

The following sections describe the valuation methodologies TVA uses to measure different financial instruments at fair value. Except for gains and losses on SERP and DCP assets, all changes in fair value of these assets and liabilities have been recorded as changes in regulatory assets, regulatory liabilities, or AOCI on TVA's Consolidated Balance Sheets and Consolidated Statements of Comprehensive Income (Loss). Except for gains and losses on SERP and DCP assets, there has been no impact to the Consolidated Statements of Operations or the Consolidated Statements of Cash Flows related to these fair value measurements.

Investment Funds

At December 31, 2023, Investment funds were comprised of $4.5 billion of equity securities and debt securities classified as trading measured at fair value. Equity and trading debt securities are held in the NDT, ART, SERP, DCP, and RP. The NDT holds funds for the ultimate decommissioning of TVA's nuclear power plants. The ART holds funds primarily for the costs related to the future closure and retirement of TVA's other long-lived assets. The balances in the NDT and ART were $3.0 billion and $1.3 billion, respectively, at December 31, 2023.

TVA established a SERP to provide benefits to selected employees of TVA which are comparable to those provided by competing organizations. The DCP is designed to provide participants with the ability to defer compensation to future periods. The RP is a non-qualified excess 401(k) plan designed to allow certain eligible employees whose contributions to the 401(k) plan are limited by Internal Revenue Service ("IRS") rules to save additional amounts for retirement and receive non-elective and matching employer contributions. The NDT, ART, SERP, DCP, and RP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity and debt market performance.

The NDT, ART, SERP, DCP, and RP are composed of multiple types of investments and are managed by external institutional investment managers. Most U.S. and international equities, U.S. Treasury inflation-protected securities, real estate investment trust securities, and cash securities and certain derivative instruments are measured based on quoted exchange prices in active markets and are classified as Level 1 valuations. Fixed-income investments, high-yield fixed-income investments, currencies, and most derivative instruments are non-exchange traded and are classified as Level 2 valuations. These measurements are based on market and income approaches with observable market inputs.

Private equity limited partnerships, private real asset investments, and private credit investments may include holdings of investments in private real estate, venture capital, buyout, mezzanine or subordinated debt, restructuring or distressed debt,

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and special situations through funds managed by third-party investment managers. These investments generally involve a three-to-four-year period where the investor contributes capital, followed by a period of distribution, typically over several years. The investment period is generally, at a minimum, 10 years or longer. The NDT had unfunded commitments related to private equity limited partnerships of $296 million, private real assets of $110 million, and private credit of $88 million at December 31, 2023. The ART had unfunded commitments related to limited partnerships in private equity of $122 million, private real assets of $54 million, and private credit of $47 million at December 31, 2023. These investments have no redemption or limited redemption options and may also impose restrictions on the NDT's and ART's ability to liquidate their investments. There are no readily available quoted exchange prices for these investments. The fair value of these investments is based on information provided by the investment managers. These investments are valued on a quarterly basis. TVA's private equity limited partnerships, private real asset investments, and private credit investments are valued at net asset values ("NAV") as a practical expedient for fair value. TVA classifies its interest in these types of investments as investments measured at NAV in the fair value hierarchy.

Commingled funds represent investment funds comprising multiple individual financial instruments. The commingled funds held by the NDT, ART, SERP, DCP, and RP consist of either a single class of securities, such as equity, debt, or foreign currency securities, or multiple classes of securities. All underlying positions in these commingled funds are either exchange traded or measured using observable inputs for similar instruments. The fair value of commingled funds is based on NAV per fund share (the unit of account), derived from the prices of the underlying securities in the funds. These commingled funds can be redeemed at the measurement date NAV and are classified as Commingled funds measured at NAV in the fair value hierarchy.

Realized and unrealized gains and losses on equity and trading debt securities are recognized in current earnings and are based on average cost. The gains and losses of the NDT and ART are subsequently reclassified to a regulatory asset or liability account in accordance with TVA's regulatory accounting policy. See Note 1 — Summary of Significant Accounting Policies of the Notes to Consolidated Financial Statements in the Annual Report and Note 8 — Regulatory Assets and Liabilities. TVA recorded unrealized gains and losses related to its equity and trading debt securities held during each period as follows:

Unrealized Investment Gains (Losses)(1) (in millions)
		Three Months Ended December 31
Fund	Financial Statement Presentation	2023		2022
NDT	Regulatory assets(2)	$	197	$	136
ART	Regulatory assets(3)	89		69
SERP	Other income, net	7		3
DCP	Other income, net	1		—

Notes

(1) Employee contributions to the RP began in the second quarter of 2023. As of December 31, 2023, the unrealized gains for the RP were less than $1 million, and therefore were not represented in the table above.

(2) Includes $61 million and $20 million of unrealized gains related to NDT equity securities (excluding commingled funds) for the three months ended December 31, 2023 and 2022, respectively.

(3) Includes $18 million and $10 million of unrealized gains related to ART equity securities (excluding commingled funds) for the three months ended December 31, 2023 and 2022, respectively.

Currency and Interest Rate Swap Derivatives

See Note 13 — Risk Management Activities and Derivative Transactions — Cash Flow Hedging Strategy for Currency Swaps and Derivatives Not Receiving Hedge Accounting Treatment for a discussion of the nature, purpose, and contingent features of TVA's currency swaps and interest rate swaps. These swaps are classified as Level 2 valuations and are valued based on income approaches using observable market inputs for similar instruments.

Commodity Contract Derivatives and Commodity Derivatives under the FHP

Commodity Contract Derivatives. Most of these derivative contracts are valued based on market approaches, which utilize short-term and mid-term market-quoted prices from an external industry brokerage service. These contracts are classified as Level 2 valuations.

Commodity Derivatives under the FHP. Swap contracts are valued using a pricing model based on New York Mercantile Exchange inputs and are subject to nonperformance risk outside of the exit price. These contracts are classified as Level 2 valuations.

See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP.

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Nonperformance Risk

The assessment of nonperformance risk, which includes credit risk, considers changes in current market conditions, readily available information on nonperformance risk, letters of credit, collateral, other arrangements available, and the nature of master netting arrangements. TVA is a counterparty to currency swaps, interest rate swaps, commodity contracts, and other derivatives which subject TVA to nonperformance risk. Nonperformance risk on the majority of investments and certain exchange-traded instruments held by TVA is incorporated into the exit price that is derived from quoted market data that is used to mark the investment to market.

Nonperformance risk for most of TVA's derivative instruments is an adjustment to the asset/liability fair value. TVA adjusts for nonperformance risk, both of TVA (for liabilities) and the counterparty (for assets), by applying credit valuation adjustments ("CVAs"). TVA determines an appropriate CVA for each applicable financial instrument based on the term of the instrument and TVA's or the counterparty's credit rating as obtained from Moody's. For companies that do not have an observable credit rating, TVA uses internal analysis to assign a comparable rating to the counterparty. TVA discounts each financial instrument using the historical default rate (as reported by Moody's for CY 1983 to CY 2022) for companies with a similar credit rating over a time period consistent with the remaining term of the contract. The application of CVAs resulted in a $1 million decrease in the fair value of assets and a $1 million decrease in the fair value of liabilities at December 31, 2023.

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Fair Value Measurements

The following tables set forth by level, within the fair value hierarchy, TVA's financial assets and liabilities that were measured at fair value on a recurring basis at December 31, 2023, and September 30, 2023. Financial assets and liabilities have been classified in their entirety based on the lowest level of input that is significant to the fair value measurement. TVA's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the determination of the fair value of the assets and liabilities and their classification in the fair value hierarchy levels.

Fair Value Measurements At December 31, 2023 (in millions)
	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Assets
Investments
Equity securities	$	684	$	—	$	—	$	684
Government debt securities(1)	453		69		—		522
Corporate debt securities(2)	—		321		—		321
Mortgage and asset-backed securities	—		37		—		37
Institutional mutual funds	309		—		—		309
Forward debt securities contracts	—		3		—		3
Cash equivalents and other short-term investments	—		163		—		163
Private equity funds measured at net asset value(3)	—		—		—		657
Private real asset funds measured at net asset value(3)	—		—		—		408
Private credit funds measured at net asset value(3)	—		—		—		184
Commingled funds measured at net asset value(3)	—		—		—		1,184
Total investments	1,446		593		—		4,472
Commodity contract derivatives	—		31		—		31
Total	$	1,446	$	624	$	—	$	4,503
	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Liabilities
Currency swaps(4)	$	—	$	121	$	—	$	121
Interest rate swaps	—		818		—		818
Commodity contract derivatives	—		2		—		2
Commodity derivatives under the FHP	—		309		—		309
Total	$	—	$	1,250	$	—	$	1,250

Notes

(1) Includes securities of government-sponsored entities, including $453 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.

(2) Includes both U.S. and foreign debt.

(3) Certain investments that are measured at fair value using the NAV or its equivalent (alternative investments) have not been categorized in the fair value hierarchy. The inputs to these fair value measurements include underlying NAVs, discounted cash flow valuations, comparable market valuations, and adjustments for currency, credit, liquidity, and other risks. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented on the Consolidated Balance Sheets.

(4) TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

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Fair Value Measurements At September 30, 2023 (in millions)
	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Assets
Investments
Equity securities	$	608	$	—	$	—	$	608
Government debt securities(1)(2)	391		60		—		451
Corporate debt securities(3)	—		300		—		300
Mortgage and asset-backed securities	—		36		—		36
Institutional mutual funds	288		—		—		288
Forward debt securities contracts	—		11		—		11
Cash equivalents and other short-term investments(2)	—		145		—		145
Private equity funds measured at net asset value(4)	—		—		—		583
Private real asset funds measured at net asset value(4)	—		—		—		387
Private credit funds measured at net asset value(4)	—		—		—		158
Commingled funds measured at net asset value(2)(4)	—		—		—		1,156
Total investments	1,287		552		—		4,123
Interest rate swaps	—		4		—		4
Commodity contract derivatives	—		33		—		33
Total	$	1,287	$	589	$	—	$	4,160
	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Liabilities
Currency swaps(5)	$	—	$	141	$	—	$	141
Interest rate swaps	—		662		—		662
Commodity contract derivatives	—		2		—		2
Commodity derivatives under the FHP	—		186		—		186
Total	$	—	$	991	$	—	$	991

Notes

(1) Includes securities of government-sponsored entities, including $391 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.

(2) At September 30, 2023, $104 million previously classified as Level 1 Cash equivalents and other short-term investments have been reclassified to Level 1 Government debt securities to conform with current year presentation. At September 30, 2023, $21 million previously classified as Level 2 Cash equivalents and other short-term investments have been reclassified to Commingled funds measured at net asset value to conform with current year presentation.

(3) Includes both U.S. and foreign debt.

(4) Certain investments that are measured at fair value using the NAV or its equivalent (alternative investments) have not been categorized in the fair value hierarchy. The inputs to these fair value measurements include underlying NAVs, discounted cash flow valuations, comparable market valuations, and adjustments for currency, credit, liquidity, and other risks. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented on the Consolidated Balance Sheets.

(5)  TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

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Other Financial Instruments Not Recorded at Fair Value

TVA uses the methods and assumptions described below to estimate the fair value of each significant class of financial instruments. The fair value of the financial instruments held at December 31, 2023, and September 30, 2023, may not be representative of the actual gains or losses that will be recorded when these instruments mature or are called or presented for early redemption. The estimated values of TVA's financial instruments not recorded at fair value at December 31, 2023, and September 30, 2023, were as follows:

Estimated Values of Financial Instruments Not Recorded at Fair Value (in millions)
		At December 31, 2023				At September 30, 2023
	Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value
EnergyRight® receivables, net (including current portion)	Level 2	$	59	$	55	$	59	$	55
Loans and other long-term receivables, net (including current portion)	Level 2	105		97		104		96
EnergyRight® financing obligations (including current portion)	Level 2	69		81		69		81
Unfunded loan commitments	Level 2	—		—		—		1
Membership interests of VIEs subject to mandatory redemption (including current portion)	Level 2	18		20		18		19
Long-term outstanding power bonds, net (including current maturities)	Level 2	18,889		19,079		18,866		17,963
Long-term debt of VIEs, net (including current maturities)	Level 2	968		987		968		927

The carrying value of Cash and cash equivalents, Restricted cash and cash equivalents, Accounts receivable, net, and Short-term debt, net approximate their fair values.

The fair value for loans and other long-term receivables is estimated by determining the present value of future cash flows using a discount rate equal to lending rates for similar loans made to borrowers with similar credit ratings and for similar remaining maturities, where applicable. The fair value of long-term debt and membership interests of VIEs subject to mandatory redemption is estimated by determining the present value of future cash flows using current market rates for similar obligations, giving effect to credit ratings and remaining maturities.

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15.  Revenue

Revenue from Sales of Electricity

TVA's revenue from contracts with customers is primarily derived from the generation and sale of electricity to its customers and is included in Revenue from sales of electricity on the Consolidated Statements of Operations. Electricity is sold primarily to LPCs for distribution to their end-use customers. In addition, TVA sells electricity to directly served industrial companies, federal agencies, and others.

LPC sales

Approximately 91 percent of TVA's Revenue from sales of electricity for both the three months ended December 31, 2023 and 2022, was from LPCs, which then distribute the power to their customers using their own distribution systems. Power is delivered to each LPC at delivery points within the LPC's service territory. TVA recognizes revenue when the customer takes possession of the power at the delivery point. For power sales, the performance obligation to deliver power is satisfied in a series over time because the sales of electricity over the term of the customer contract are a series of distinct goods that are substantially the same and have the same pattern of transfer to the customer. TVA has no continuing performance obligations subsequent to delivery. Using the output method for revenue recognition provides a faithful depiction of the transfer of electricity as customers obtain control of the power and benefit from its use at delivery. Additionally, TVA has an enforceable right to consideration for energy delivered at any discrete point in time and will recognize revenue at an amount that reflects the consideration to which TVA is entitled for the energy delivered. The amount of revenue is based on contractual prices approved by the TVA Board. Customers are invoiced monthly for power delivered as measured by meters located at the delivery points. The net transaction price is offset by certain credits available to customers that are known at the time of billing. Credits are designed to achieve objectives of the TVA Act and include items such as hydro preference credits for residential customers of LPCs, economic development credits to promote growth in the Tennessee Valley, wholesale bill credits to maintain long-term partnerships with LPCs, and demand response credits allowing TVA to reduce industrial customer usage in periods of peak demand to balance system demand. Payments are typically due within approximately one month of invoice issuance.

Directly served customers

Directly served customers, including industrial customers, federal agencies, and other customers, take power for their own consumption. Similar to LPCs, power is delivered to a delivery point, at which time the customer takes possession and TVA recognizes revenue. For all power sales, the performance obligation to deliver power is satisfied in a series over time since the sales of electricity over the term of the customer contract are a series of distinct goods that are substantially the same and have the same pattern of transfer to the customer. TVA has no continuing performance obligations subsequent to delivery. Using the output method for revenue recognition provides a faithful depiction of the transfer of electricity as customers obtain control of the power and benefit from its use at delivery. Additionally, TVA has an enforceable right to consideration for energy delivered at any discrete point in time and will recognize revenue at an amount that reflects the consideration to which TVA is entitled for the energy delivered. The amount of revenue is based on contractual prices approved by the TVA Board. Customers are invoiced monthly for power delivered as measured by meters located at the delivery points. The net transaction price is offset by certain credits available to customers that are known at the time of billing. Examples of credits include items such as economic development credits to promote growth in the Tennessee Valley and demand response credits allowing TVA to reduce industrial customer usage in periods of peak demand to balance system demand. Payments are typically due within approximately one month of invoice issuance.

Other Revenue

Other revenue consists primarily of wheeling and network transmission charges, sales of excess steam that is a by-product of power production, delivery point charges for interconnection points between TVA and the customer, Renewable Energy Certificate sales, and certain other ancillary goods or services.

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Disaggregated Revenues

During the three months ended December 31, 2023, revenues generated from TVA's electricity sales were $2.7 billion, and accounted for virtually all of TVA's revenues. TVA's operating revenues by state for the three months ended December 31, 2023 and 2022, are detailed in the table below:

Operating Revenues By State (in millions)
	Three Months Ended December 31
	2023		2022
Alabama	$	408	$	428
Georgia	69		76
Kentucky	177		198
Mississippi	255		278
North Carolina	23		25
Tennessee	1,789		1,941
Virginia	11		13
Subtotal	2,732		2,959
Off-system sales	2		4
Revenue capitalized during pre-commercial plant operations(1)	(3)		—
Revenue from sales of electricity	2,731		2,963
Other revenue	34		52
Total operating revenues	$	2,765	$	3,015

Note

(1) Represents revenue capitalized during pre-commercial operations at Paradise Combustion Turbine Units 5-7.

TVA's operating revenues by customer type for the three months ended December 31, 2023 and 2022, are detailed in the table below:

Operating Revenues by Customer Type (in millions)
	Three Months Ended December 31
	2023		2022
Revenue from sales of electricity
Local power companies	$	2,487	$	2,706
Industries directly served	217		225
Federal agencies and other	30		32
Revenue capitalized during pre-commercial plant operations(1)	(3)		—
Revenue from sales of electricity	2,731		2,963
Other revenue	34		52
Total operating revenues	$	2,765	$	3,015

Note

(1) Represents revenue capitalized during pre-commercial operations at Paradise Combustion Turbine Units 5-7.

TVA and LPCs continue to work together to meet the changing needs of consumers around the Tennessee Valley. In 2019, the TVA Board approved a partnership agreement option that better aligns the length of LPC power contracts with TVA's long-term commitments. Under the partnership arrangement, the LPC power contracts automatically renew each year and have a 20-year termination notice. The partnership arrangements can be terminated under certain circumstances, including TVA's failure to limit rate increases as provided for in the agreements going forward. Participating LPCs receive benefits including a 3.1 percent wholesale bill credit in exchange for their long-term commitment, which enables TVA to recover its long-term financial commitments over a commensurate period. The total wholesale bill credits to LPCs participating in the Partnership Agreement were $47 million and $48 million for the three months ended December 31, 2023 and 2022, respectively. In 2020, TVA provided participating LPCs a flexibility option, named Generation Flexibility, that allows them to locally generate or purchase up to approximately five percent of their average total hourly energy sales over a certain time period in order to meet their individual customers' needs. Revised flexibility agreements were made available to LPCs in 2023 which permit projects to be located anywhere in TVA's service area, either connected to the LPC distribution system or TVA's transmission system, and make it easier for LPCs to partner in projects. As of December 31, 2023, 147 LPCs had signed the Partnership Agreement with TVA,

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and 92 LPCs had signed a Power Supply Flexibility Agreement.

The number of LPCs by contract arrangement, the revenues derived from such arrangements for the three months ended December 31, 2023, and the percentage those revenues comprised of TVA's total operating revenues for the same period, are summarized in the table below:

TVA Local Power Company Contracts At or for the Three Months Ended December 31, 2023
Contract Arrangements(1)	Number of LPCs	Revenue from Sales of Electricity to LPCs (in millions)		Percentage of Total Operating Revenues
20-year termination notice	147	$	2,156	78.0	%
5-year termination notice	6	331		12.0	%
Total	153	$	2,487	90.0	%

Note

(1) Ordinarily, the LPCs and TVA have the same termination notice period; however, in a contract with one of the LPCs with a five-year termination notice, TVA has a 10-year termination notice (which becomes a five-year termination notice if TVA loses its discretionary wholesale rate-setting authority). Certain LPCs have five-year termination notices or a shorter period if any act of Congress, court decision, or regulatory change requires or permits that election.

TVA's two largest LPCs — Memphis Light, Gas and Water Division ("MLGW") and Nashville Electric Service ("NES") — have contracts with a five-year and a 20-year termination notice period, respectively. Sales to MLGW and NES each accounted for eight percent of TVA's total operating revenues for both the three months ended December 31, 2023 and the three months ended December 31, 2022.

Contract Balances

Contract assets represent an entity's right to consideration in exchange for goods and services that the entity has transferred to customers. TVA did not have any material contract assets at December 31, 2023.

Contract liabilities represent an entity's obligations to transfer goods or services to customers for which the entity has received consideration (or an amount of consideration is due) from the customers. These contract liabilities are primarily related to upfront consideration received prior to the satisfaction of the performance obligation. See Economic Development Incentives below and Note 10 — Other Long-Term Liabilities — Long-Term Deferred Revenue.

Economic Development Incentives. Under certain economic development programs, TVA offers incentives to existing and potential power customers in targeted business sectors that make multi-year commitments to invest in the Tennessee Valley. TVA records those incentives as reductions of revenue. Incentives recorded as a reduction to revenue were $73 million and $82 million for the three months ended December 31, 2023 and 2022, respectively. Incentives that have been approved but have not been paid are recorded in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. At December 31, 2023, and September 30, 2023, the outstanding unpaid incentives were $181 million and $188 million, respectively. Incentives that have been paid out may be subject to claw back if the customer fails to meet certain program requirements.

16.  Other Income, Net

Income and expenses not related to TVA's operating activities are summarized in the following table:

Other Income, Net (in millions)
	Three Months Ended December 31
	2023		2022
Interest income	$	10	$	7
External services	4		3
Gains on investments	9		6
Total other income, net	$	23	$	16

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17. Supplemental Cash Flow Information

Construction in progress and nuclear fuel expenditures included in Accounts payable and accrued liabilities at December 31, 2023 and 2022, were $552 million and $363 million, respectively, and are excluded from the Consolidated Statements of Cash Flows for the three months ended December 31, 2023 and 2022, as non-cash investing activities. ARO project accruals included in Accounts payable and accrued liabilities at December 31, 2023 and 2022 were $46 million and $62 million, respectively, and are excluded from the Consolidated Statements of Cash Flows for the three months ended December 31, 2023 and 2022, as non-cash operating activities.

Cash flows from swap contracts that are accounted for as hedges are classified in the same category as the item being

hedged or on a basis consistent with the nature of the instrument.

18.  Benefit Plans

TVA sponsors a pension plan that covers most of its full-time employees hired before July 1, 2014, a qualified defined contribution plan ("401(k) plan") that covers most of its full-time employees, two unfunded post-retirement health care plans that provide for non-vested contributions toward the cost of eligible retirees' medical coverage, other post-employment benefits, such as workers' compensation, the SERP, and the RP. The pension plan and the 401(k) plan are administered by a separate legal entity, the TVA Retirement System ("TVARS"), which is governed by its own board of directors.

The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the three months ended December 31, 2023 and 2022, were as follows:

Components of TVA's Benefit Plans(1) (in millions)
	For the Three Months Ended December 31
	Pension Benefits				Other Post-Retirement Benefits
	2023		2022		2023		2022
Service cost	$	7	$	9	$	3	$	3
Interest cost	144		142		5		5
Expected return on plan assets	(124)		(123)		—		—
Amortization of prior service credit	(22)		(22)		(4)		(4)
Recognized net actuarial loss (gain)	25		34		(1)		—
Total net periodic benefit cost as actuarially determined	30		40		3		4
Amount expensed due to actions of regulator	—		19		—		—
Total net periodic benefit cost	$	30	$	59	$	3	$	4

Note

(1) The components of net benefit cost other than the service cost component are included in Other net periodic benefit cost on the Consolidated Statements of Operations.

TVA's minimum required pension plan contribution for 2024 is $300 million. TVA contributes $25 million per month to TVARS and as of December 31, 2023, had contributed $75 million. The remaining $225 million will be contributed by September 30, 2024. For the three months ended December 31, 2023, TVA also contributed $35 million to the 401(k) plan and $8 million (net of $1 million in rebates) to the other post-retirement plans. TVA expects to contribute $6 million to the SERP in 2024.

19. Collaborative Arrangement

In 2023, TVA, Ontario Power Generation, BWRX TCA sp. z.o.o., and GE Hitachi Nuclear Energy ("GEH") entered into a multi-party collaborative arrangement to advance the global deployment of the GEH BWRX-300 small modular reactor. GEH is responsible for standard design development. Under the agreement, TVA will contribute up to $88 million for design costs incurred by GEH through 2026. At the time feasibility is determined, TVA will have the right to use the design and may receive additional economic benefits.

Payments pursuant to the agreement are recorded as research and development expense, which is reflected as Operating and maintenance expense on TVA's Consolidated Statement of Operations in the period incurred. TVA recorded $9 million and $16 million of expenses related to this agreement for the three months ended December 31, 2023 and 2022, respectively. TVA also had a $6 million letter of credit posted under this arrangement at December 31, 2023.

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20.  Contingencies and Legal Proceedings

Contingencies

Nuclear Insurance.  Section 170 of the Atomic Energy Act, commonly known as the Price-Anderson Act, provides a layered framework of financial protection to compensate for liability claims of members of the public for personal injury and property damages arising from a nuclear incident in the U.S. This financial protection consists of two layers of coverage. The primary level is private insurance underwritten by American Nuclear Insurers and provides public liability insurance coverage of $450 million for each nuclear power plant licensed to operate. If this amount is not sufficient to cover claims arising from a nuclear incident, the second level, Secondary Financial Protection, applies. Within the Secondary Financial Protection level, the licensee of each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident of fault, up to a maximum of approximately $166 million per reactor per incident. With TVA's seven reactors, the maximum total contingent obligation per incident is $1.2 billion. This retrospective premium is payable at a maximum rate currently set at approximately $25 million per year per nuclear incident per reactor. Currently, 95 reactors are participating in the Secondary Financial Protection program.

In the event that a nuclear incident results in public liability claims, the primary level provided by American Nuclear Insurers combined with the Secondary Financial Protection should provide up to $16.2 billion in coverage.

Federal law requires that each Nuclear Regulatory Commission ("NRC") power reactor licensee obtain property insurance from private sources to cover the cost of stabilizing and decontaminating a reactor and its station site after an accident. TVA carries property, decommissioning liability, and decontamination liability insurance from Nuclear Electric Insurance Limited ("NEIL") and European Mutual Association for Nuclear Insurance. The limits available for a loss are up to $2.1 billion for two of TVA's nuclear sites and up to $2.8 billion for the remaining site. Some of this insurance may require the payment of retrospective premiums up to a maximum of approximately $114 million.

TVA purchases accidental outage (business interruption) insurance for TVA's nuclear sites from NEIL.  In the event that an accident covered by this policy takes a nuclear unit offline or keeps a nuclear unit offline, NEIL will pay TVA, after a waiting period, an indemnity (a set dollar amount per week) with a maximum indemnity of $490 million per unit.  This insurance policy may require the payment of retrospective premiums up to a maximum of approximately $44 million, but only to the extent the retrospective premium is deemed necessary by the NEIL Board of Directors to pay losses unable to be covered by NEIL's surplus.

Decommissioning Costs.  TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets related primarily to nuclear generating plants, coal-fired generating plants, hydroelectric generating plants/dams, transmission structures, and other property-related assets. See Note 11 — Asset Retirement Obligations.

Nuclear Decommissioning.  Provision for decommissioning costs of nuclear generating units is based on options prescribed by the NRC procedures to dismantle and decontaminate the facilities to meet the NRC criteria for license termination. At December 31, 2023, $3.8 billion, representing the discounted value of future estimated nuclear decommissioning costs, was included in nuclear AROs.  The actual decommissioning costs may vary from the derived estimates because of, among other things, changes in current assumptions, such as the assumed dates of decommissioning, changes in regulatory requirements, changes in technology, and changes in the cost of labor, materials, and equipment.  Utilities that own and operate nuclear plants are required to use different procedures in calculating nuclear decommissioning costs under GAAP than those that are used in calculating nuclear decommissioning costs when reporting to the NRC.  The two sets of procedures produce different estimates for the costs of decommissioning primarily because of differences in the underlying assumptions. TVA bases its nuclear decommissioning estimates on site-specific cost studies. The most recent study was approved and implemented in September 2022. Site-specific cost studies are updated for each of TVA's nuclear units at least every five years.

TVA maintains an NDT to provide funding for the ultimate decommissioning of its nuclear power plants.  See Note 14 — Fair Value Measurements — Investment Funds. TVA monitors the value of its NDT and believes that, over the long term and before cessation of nuclear plant operations and commencement of decommissioning activities, adequate funds from investments and additional contributions, if necessary, will be available to support decommissioning.  TVA's operating nuclear power units are licensed through various dates between 2033 - 2055, depending on the unit.  It may be possible to extend the operating life of some of the units with approval from the NRC. See Note 8 — Regulatory Assets and Liabilities and Note 11 — Asset Retirement Obligations.

Non-Nuclear Decommissioning.  At December 31, 2023, $3.7 billion, representing the discounted value of future estimated non-nuclear decommissioning costs, was included in non-nuclear AROs.  This decommissioning cost estimate involves estimating the amount and timing of future expenditures and making judgments concerning whether or not such costs are considered a legal obligation.  Estimating the amount and timing of future expenditures includes, among other things, making projections of the timing and duration of the asset retirement process and how costs will escalate with inflation.  The actual decommissioning costs may vary from the derived estimates because of changes in current assumptions, such as the assumed dates of decommissioning, changes in regulatory requirements, changes in technology, and changes in the cost of labor, materials, and equipment. TVA updates its underlying assumptions for non-nuclear decommissioning AROs at least every five

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years. However, material changes in underlying assumptions that impact the amount and timing of undiscounted cash flows are continuously monitored and incorporated into ARO balances in the period identified.

TVA maintains an ART to help fund the ultimate decommissioning of its non-nuclear power assets.  See Note 14 — Fair Value Measurements — Investment Funds. Estimates involved in determining if additional funding will be made to the ART include inflation rate, rate of return projections on the fund investments, and the planned use of other sources to fund decommissioning costs. See Note 8 — Regulatory Assets and Liabilities and Note 11 — Asset Retirement Obligations.

Environmental Matters. TVA's generation activities, like those across the utility industry and in other industrial sectors, are subject to federal, state, and local environmental laws and regulations.  Major areas of regulation affecting TVA's activities include air quality control, greenhouse gas ("GHG") emissions, water quality control, and management and disposal of solid and hazardous wastes.  Regulations in these major areas continue to become more stringent and have, and will continue to have, a particular emphasis on climate change, renewable generation, and energy efficiency.

TVA has incurred, and expects to continue to incur, substantial capital and operating and maintenance costs to comply with evolving environmental requirements primarily associated with, but not limited to, the operation of TVA's coal-fired and natural gas-fired generating units in general and emissions of pollutants from those units.  Environmental requirements placed on the operation of coal-fired and other generating units using fossil fuels such as oil and natural gas will likely continue to become more restrictive over time. Failure to comply with environmental and safety requirements can result in enforcement actions and litigation, which can lead to the imposition of significant civil liability, including fines and penalties, criminal sanctions, and/or temporary or permanent closure of non-compliant facilities. Historical non-compliance can also lead to difficulty in renewing existing permits, as well as difficulty in obtaining permits to bring new generation facilities online. Other obstacles to renewal or permitting of new facilities include a proliferation of non-government organizations seeking to use litigation tools to delay or stop altogether permitting of new fossil fuel facilities in favor of renewable energy projects.

TVA estimates that compliance with existing Clean Air Act requirements (excluding GHG requirements and new or proposed regulations) could lead to costs of $228 million from 2024 to 2028, which include existing controls capital projects and air operations and maintenance projects. TVA also estimates additional expenditures of $1.6 billion from 2024 to 2028 relating to TVA's coal combustion residuals ("CCR") Program, as well as expenditures of $197 million from 2024 to 2028 relating to compliance with Clean Water Act requirements. Future costs could differ from these estimates if, among other things, new environmental laws or regulations become applicable to TVA or the facilities it operates, or if existing environmental laws or regulations are revised or reinterpreted.  There could also be costs that cannot reasonably be predicted at this time, due to uncertainty of actions, that could increase these estimates, and these estimates do not include expenditures expected to be incurred after 2028.

Compliance with the Environmental Protection Agency's CCR rule required implementation of a groundwater monitoring program, additional engineering, and ongoing analysis. As further analyses are performed, including evaluation of monitoring results, there is the potential for additional costs for investigation and/or remediation. These costs cannot reasonably be predicted until a final remedy is selected where required.

Liability for releases, natural resource damages, and required cleanup of hazardous substances is primarily regulated by the federal Comprehensive Environmental Response, Compensation, and Liability Act ("CERCLA"), the Resource Conservation and Recovery Act ("RCRA"), and other federal and parallel state statutes.  In a manner similar to many other governmental entities, industries, and power systems, TVA has generated or used hazardous substances over the years. TVA operations at some facilities have resulted in releases of contaminants that TVA has addressed or is addressing consistent with state and federal requirements.  At both December 31, 2023 and September 30, 2023, TVA's estimated liability for required cleanup and similar environmental work for those sites for which sufficient information is available to develop a cost estimate was approximately $16 million on a non-discounted basis and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. Additionally, the potential inclusion of new hazardous substances under CERCLA and RCRA jurisdiction could significantly affect TVA's future liability for remediating historical releases.

In August 2015, Tennessee Department of Environment and Conservation ("TDEC") issued an order that includes an iterative process through which TVA and TDEC will identify and evaluate any CCR contamination risks and, if necessary, respond to such risks. As part of this process, TVA has submitted Environmental Assessment Reports ("EARs") to TDEC, and after the EARs are approved, TVA will submit Corrective Action/Risk Assessment Plans that will identify the unacceptable risks and TVA's proposed remediation. At December 31, 2023, TVA's estimated liability for costs associated with these environmental remediation activities for sites for which sufficient information is available to develop a cost estimate was approximately $26 million and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets.

Potential Liability Associated with Workers' Exposure to CCR Materials. In response to the 2008 ash spill at Kingston Fossil Plant, TVA hired Jacobs Engineering Group, Inc. ("Jacobs") to oversee aspects of the cleanup. After the cleanup was completed, Jacobs was sued in the U.S. District Court for the Eastern District of Tennessee ("Eastern District") by employees of a contractor involved in the cleanup and family members of some of the employees. The plaintiffs alleged that Jacobs failed to take or provide proper health precautions and misled workers about the health risks associated with exposure to coal fly ash,

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which is a CCR material. The plaintiffs also alleged that exposure to the fly ash caused significant illnesses, including in some cases death. Other contractor employees and family members also filed similar lawsuits against Jacobs in the Eastern District. In the third quarter of 2023, Jacobs announced that it reached a global settlement that resolved all of these lawsuits. While TVA was not a party to any of these lawsuits, TVA may potentially have an indemnity obligation to reimburse Jacobs in some circumstances. TVA does not expect any potential liability to have a material adverse impact on its results of operations or financial condition.

Legal Proceedings

There have been no material changes to the legal proceedings described in Note 22 — Commitments and Contingencies — Legal Proceedings of the Annual Report.

ITEM 2.  MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The Management's Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") explains the results of operations and general financial condition of the Tennessee Valley Authority ("TVA"). The MD&A should be read in conjunction with the accompanying unaudited consolidated financial statements and TVA's Annual Report on Form 10-K for the year ended September 30, 2023 (the "Annual Report").

Executive Overview

TVA's operating revenues were $2.8 billion and $3.0 billion for the three months ended December 31, 2023 and 2022, respectively. Operating revenues decreased for the three months ended December 31, 2023, as compared to the same period of the prior year, primarily as a result of lower fuel rates and lower sales volume, partially offset by higher effective base rates. The lower fuel rates were primarily due to lower natural gas and purchased power prices. The decreased sales volume was driven by overall milder weather during the first quarter of 2024 as compared to the first quarter of 2023. Effective base rates were higher primarily due to the TVA Board action to increase rates 4.5 percent beginning in 2024 and the pandemic credits ending September 30, 2023.

Total operating expenses decreased $241 million for the three months ended December 31, 2023, as compared to the three months ended December 31, 2022 primarily due to a decrease in fuel and purchased power expense. Fuel and purchased power expense decreased $251 million for the three months ended December 31, 2023, as compared to the same period of the prior year, primarily due to lower natural gas and purchased power prices.

Pre-commercial plant operations began on Paradise Combustion Turbine Units 5-7 in the first quarter of 2024, and the units became operational on December 29, 2023. In addition, the first license renewal application was submitted to the Nuclear Regulatory Commission in January 2024 for the three units at Browns Ferry Nuclear Plant following the completion of a Supplemental Environmental Impact Statement.

On January 17, 2024, TVA reached a preliminary all-time record high peak power demand of approximately 34,524 megawatts ("MW"). This estimated peak was over 1,000 MW greater than TVA's previous all-time peak and nearly 1,100 MW greater than TVA's peak power demand during Winter Storm Elliott in December 2022. In addition, TVA reached a preliminary second highest all-time record high peak power demand of approximately 34,284 MW on January 21, 2024.

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Results of Operations

Sales of Electricity

Sales of electricity, which accounted for nearly all of TVA's operating revenues, were 37,335 million and 38,006 million kilowatt hours ("kWh") for the three months ended December 31, 2023 and 2022, respectively. The total sales of electricity for the three months ended December 31, 2023 include 137 million kWh of pre-commercial generation at Paradise Combustion Turbine Units 5-7. TVA sells power at wholesale rates to LPCs that then resell the power to their customers at retail rates. TVA also sells power to directly served customers, consisting primarily of federal agencies and customers with large or nonstandard loads. In addition, power exceeding TVA's system needs is sold under exchange power arrangements with certain other power systems.

The following chart compares TVA's sales of electricity by customer type for the periods indicated:

The following charts show a breakdown of TVA's energy load:        

Note

Information included in the charts above was derived from energy usage of directly served customers and customers served by LPCs during calendar

year ("CY") 2022, and these graphs will continue to be updated on a CY basis.

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Weather affects both the demand for TVA power and the price for that power. TVA uses degree days to measure the impact of weather on its power operations. Degree days measure the extent to which the TVA system 23-station average temperatures vary from 65 degrees Fahrenheit.

	Degree Days
	Variation from Normal								Change from Prior Period
	2023	Normal	Percent Variation		2022	Normal	Percent Variation		Percent Change
Heating Degree Days
Three Months Ended December 31	1,094	1,243	(12.0)	%	1,262	1,243	1.5	%	(13.3)	%
Cooling Degree Days
Three Months Ended December 31	69	61	13.1	%	9	61	(85.2)	%	666.7	%

Sales of electricity decreased approximately two percent for the three months ended December 31, 2023, as compared to the same period of the prior year. The decreased sales volume was driven by milder weather during the current quarter, which resulted from a 13 percent decline in heating degree days over the same period of the prior year. For industries directly served, sales of electricity increased primarily from business-specific factors.

Financial Results

The following table compares operating results for the three months ended December 31, 2023 and 2022:

Summary Consolidated Statements of Operations (in millions)
	Three Months Ended December 31
	2023		2022		Change		Percent Change
Operating revenues	$	2,765	$	3,015	$	(250)	(8.3)	%
Operating expenses	2,376		2,617		(241)		(9.2)	%
Operating income	389		398		(9)		(2.3)	%
Other income, net	23		16		7		43.8	%
Other net periodic benefit cost	23		51		(28)		(54.9)	%
Interest expense	262		262		—		—	%
Net income	$	127	$	101	$	26	25.7	%

Operating Revenues.  Operating revenues for the three months ended December 31, 2023 and 2022, were $2.8 billion and $3.0 billion, respectively. The following table compares TVA's operating revenues for the periods indicated:

Operating Revenues by Customer Type (in millions)
	Three Months Ended December 31
	2023		2022		Change		Percent Change
Operating revenues
Local power company customers	$	2,487	$	2,706	$	(219)	(8.1)	%
Industries directly served	217		225		(8)		(3.6)	%
Federal agencies and other	30		32		(2)		(6.3)	%
Revenue capitalized during pre-commercial plant operations(1)	(3)		—		(3)		100.0	%
Other revenue	34		52		(18)		(34.6)	%
Total operating revenues	$	2,765	$	3,015	$	(250)	(8.3)	%

Note

(1) Represents revenue capitalized during pre-commercial operations at Paradise Combustion Turbine Units 5-7.

TVA's two largest LPCs — Memphis Light, Gas and Water Division ("MLGW") and Nashville Electric Service ("NES") — have contracts with a five-year and a 20-year termination notice period, respectively. Sales to MLGW and NES each accounted for eight percent of TVA's total operating revenues for both the three months ended December 31, 2023 and the three months ended December 31, 2022.

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TVA's rate structure uses pricing signals to indicate seasons and hours of higher cost to serve its customers and to capture a portion of TVA's fixed costs in fixed charges.  The structure includes three base revenue components: time of use demand charges, time of use energy charges, and a grid access charge ("GAC").  The demand charges are based upon the customer's peak monthly usage. The energy charges are based on time differentiated kWh used by the customer.  Both of these components can be significantly impacted by weather. The GAC captures a portion of fixed costs and is offset by a corresponding reduction to the energy rates. The GAC also reduces the impact of weather variability to the overall rate structure.

TVA has a Partnership Agreement option that better aligns the length of LPC power contracts with TVA's long-term commitments. Under the partnership arrangement, the LPC power contracts automatically renew each year and have a 20-year termination notice. The partnership arrangements can be terminated under certain circumstances, including TVA's failure to limit rate increases as provided for in the agreements going forward. Participating LPCs receive benefits including a 3.1 percent wholesale bill credit in exchange for their long-term commitment, which enables TVA to recover its long-term financial commitments over a commensurate period. As of December 31, 2023, 147 LPCs had signed the 20-year Partnership Agreement with TVA.

In addition to base revenues, the rate structure includes a separate fuel rate that includes the costs of natural gas, fuel oil, purchased power, coal, emission allowances, nuclear fuel, and other fuel-related commodities; realized gains and losses on derivatives purchased to hedge the costs of such commodities; and payments to states and counties in lieu of taxes ("tax equivalents") associated with the fuel cost adjustments.

TVA is required to charge rates for power that will produce gross revenues sufficient to cover various costs as discussed in Part I, Item I, Business — Rates of the Annual Report. In August 2023, the TVA Board approved a 4.5 percent wholesale rate increase (excluding fuel) effective October 1, 2023 primarily due to additional capacity needs and rising costs. This rate adjustment is estimated to produce an additional $405 million of revenue during 2024.

The changes in revenue components are summarized below:

Changes in Revenue Components (in millions)
	Three Months Ended December 31
	2023		2022		Change
Base revenue
Energy revenue	$	1,112	$	1,096	$	16
Demand revenue	868		885		(17)
Grid access charge	156		147		9
Pre-commercial operations(1)	(3)		—		(3)
Long-term partnership credits for LPCs	(47)		(48)		1
Pandemic relief credits(2)	—		(53)		53
Other charges and credits(3)	(140)		(149)		9
Total base revenue	1,946		1,878		68
Fuel cost recovery	783		1,081		(298)
Off-system sales	2		4		(2)
Revenue from sales of electricity	2,731		2,963		(232)
Other revenue	34		52		(18)
Total operating revenues	$	2,765	$	3,015	$	(250)

Notes

(1) Represents revenue capitalized during pre-commercial operations at Paradise Combustion Turbine Units 5-7.

(2) The pandemic credits ended September 30, 2023.

(3) Includes economic development credits to promote growth in the Tennessee Valley, hydro preference credits for residential customers of LPCs, and demand response credits allowing TVA to reduce industrial customer usage in periods of peak demand to balance system demand. See Note 15 — Revenue.

Operating revenues decreased $250 million for the three months ended December 31, 2023, as compared to the same period of the prior year, primarily due to a $298 million decrease in fuel cost recovery revenue. The $298 million decrease in fuel cost recovery revenue was driven by a $277 million decrease attributable to lower fuel rates and a $21 million decrease attributable to lower sales volume in the first quarter of 2024. The lower fuel rates were primarily due to lower natural gas and purchased power prices. The lower sales volume was driven by milder weather in the Tennessee Valley region for the current quarter as compared to the same period of the prior year. The $68 million increase in base revenue was driven by a $175 million increase attributable to higher effective base rates partially offset by a $107 million decrease attributable to lower sales volume. The increase in effective base rates was primarily due to the TVA Board action to increase rates 4.5 percent beginning in 2024 and the pandemic credits ending September 30, 2023.

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See Sales of Electricity above for further discussion of the change in the volume of sales of electricity and Operating Expenses below for further discussion of the change in fuel expense.

Operating Expenses. Operating expense components as a percentage of total operating expenses for the three months ended December 31, 2023 and December 31, 2022, consisted of the following:

Operating Expenses (in millions)
	Three Months Ended December 31
	2023		2022		Change		Percent Change
Operating expenses
Fuel	$	496	$	615	$	(119)	(19.3)	%
Purchased power	359		491		(132)		(26.9)	%
Operating and maintenance	867		827		40		4.8	%
Depreciation and amortization	521		533		(12)		(2.3)	%
Tax equivalents	133		151		(18)		(11.9)	%
Total operating expenses	$	2,376	$	2,617	$	(241)	(9.2)	%

Fuel expense decreased $119 million for the three months ended December 31, 2023, as compared to the same period of the prior year. This decrease was primarily due to a decrease in effective fuel rates due to lower natural gas prices, resulting in a $179 million decrease in fuel expenses. Partially offsetting these decreases was an increase of $62 million related primarily to the deferral of unplanned fuel costs in December 2022.

Purchased power expense decreased $132 million for the three months ended December 31, 2023, as compared to the same period of the prior year. This decrease was primarily due to lower purchased power market prices, resulting in a decrease of $166 million, as well as lower demand for energy due to overall milder weather and higher availability of nuclear generation resulting in an additional decrease of $29 million. Partially offsetting these decreases was an increase of $63 million related primarily to the deferral of unplanned purchased power costs in December 2022.

Operating and maintenance expense increased $40 million for the three months ended December 31, 2023, as compared to the same period of the prior year. This increase was primarily due to $33 million of increased payroll and benefit costs primarily due to labor escalation for cost of living increases and additional headcount to support operational needs and $20 million of increased contract labor costs primarily related to power operations performance improvement activities and natural gas project work. Partially offsetting these increases was a $33 million decrease in outage expense primarily due to fewer nuclear refueling outages.

Depreciation and amortization expense decreased $12 million for the three months ended December 31, 2023, as compared to the same period of the prior year.  The decrease was primarily driven by a decrease in depreciation expense of $43 million related to the decision to retire Bull Run, as Bull Run became fully depreciated in the fourth quarter of 2023. Partially offsetting this decrease was a $16 million increase in additional depreciation related to TVA's decision to retire Cumberland Fossil Plant ("Cumberland"). Additionally, there was an increase due to depreciation of additions to net completed plant.

Tax equivalents expense decreased $18 million for the three months ended December 31, 2023, as compared to the

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same period of the prior year. The change is primarily driven by a decrease in the tax equivalents collected in the fuel cost recovery.

Generating Sources. The following table shows TVA's generation and purchased power by generating source as a percentage of all electrical power generated and purchased (based on kWh) for the periods indicated:

Total Power Supply by Generating Source For the three months ended December 31 (millions of kWh)
	2023			2022
Nuclear	17,851	47	%	16,428	42	%
Natural gas and/or oil-fired	7,513	20	%	7,806	20	%
Coal-fired	4,320	11	%	4,513	12	%
Hydroelectric	2,496	7	%	3,542	9	%
Total TVA-operated generation facilities(1)(2)	32,180	85	%	32,289	83	%
Purchased power (natural gas and/or oil-fired)(3)	3,424	9	%	3,751	10	%
Purchased power (other renewables)(4)	1,686	4	%	1,485	4	%
Purchased power (coal-fired)	595	2	%	742	2	%
Purchased power (hydroelectric)	146	—	%	393	1	%
Total purchased power(2)	5,851	15	%	6,371	17	%
Total power supply	38,031	100	%	38,660	100	%

Notes

(1) Generation from TVA-owned renewable resources (non-hydroelectric) is less than one percent for all periods shown and therefore is not represented in the table above.

(2) Raccoon Mountain Pumped-Storage Plant net generation is allocated against each TVA-operated generation facility and purchased power type for both the three months ended December 31, 2023, and the three months ended December 31, 2022. See Part I, Item 1, Business — Power Supply and Load Management Resources — Hydroelectric Pumped-Storage in the Annual Report for a discussion of Raccoon Mountain Pumped-Storage Plant.

(3) Purchased power (natural gas and/or oil-fired) includes generation from Caledonia Combined Cycle Plant ("Caledonia CC"), which is currently a leased facility operated by TVA. Generation from Caledonia CC was 910 million kWh and 1,041 million kWh for the three months ended December 31, 2023 and 2022, respectively.

(4) Purchased power (other renewables) includes purchased power from the following renewable sources: solar, wind, biomass, and renewable cogeneration. TVA sells the Renewable Energy Certificates resulting from some of this purchased power to certain customers.

In addition to power supply sources included here, TVA offers energy efficiency programs that effectively reduce energy needs. In 2024, TVA plans to invest $104 million on its energy efficiency programs and anticipates approximately 310 gigawatt hours of net incremental energy efficiency savings.

Interest Expense.  Interest expense and interest rates for the three months ended December 31, 2023 and the three months ended December 31, 2022, were as follows:

Interest Expense and Rates (in millions)
	Three Months Ended December 31
	2023			2022			Percent  Change
Interest expense(1)	$	262		$	262		—	%
Average blended debt balance(2)	$	20,610		$	20,236		1.8	%
Average blended interest rate(3)	4.89		%	4.99		%	(2.0)	%

Notes

(1) Includes amortization of debt discounts, issuance, and reacquisition costs, net.

(2) Includes average balances of long-term power bonds, debt of variable interest entities ("VIEs"), and discount notes.

(3) Includes interest on long-term power bonds, debt of VIE, and discount notes.

Total interest expense was flat for the three months ended December 31, 2023, as compared to the same period of the prior year. This resulted from higher average balances of long-term debt and higher average rates on short-term debt, that were offset primarily by lower average rates on long-term debt and lower average balances of short-term debt.

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Liquidity and Capital Resources

Sources of Liquidity

TVA depends on various sources of liquidity to meet cash needs and contingencies. TVA's primary sources of liquidity are cash from operations and proceeds from the issuance of short-term debt in the form of discount notes, along with periodic issuances of long-term debt. TVA's balance of short-term debt typically changes frequently as TVA issues discount notes to meet short-term cash needs and pay scheduled maturities of discount notes and long-term debt. TVA’s next significant power bond maturity is $1.0 billion in September 2024. The periodic amounts of short-term debt issued are determined by near-term expectations for cash receipts, cash expenditures, and funding needs, while seeking to maintain a target range of cash and cash equivalents on hand. TVA may hold higher cash balances from time to time in response to potential market volatility or other business conditions. In addition, cash balances may include collateral received from counterparties.

In addition to cash from operations and proceeds from the issuance of short-term and long-term debt, TVA's sources of liquidity include four long-term revolving credit facilities totaling $2.7 billion, a $150 million credit facility with the United States Department of the Treasury ("U.S. Treasury"), and proceeds from other financings. See Note 12 — Debt and Other Obligations — Credit Facility Agreements. The TVA Board authorized TVA to issue power bonds and enter into other financing arrangements in an aggregate amount not to exceed $4.0 billion during 2024. Other financing arrangements may include lease financings and sales of receivables, loans, or other assets.

The Tennessee Valley Authority Act of 1933, as amended ("TVA Act"), authorizes TVA to issue Bonds in an amount not to exceed $30.0 billion outstanding at any time. Bonds outstanding, excluding unamortized discounts and premiums and net exchange gains from foreign currency transactions, at December 31, 2023, were $20.1 billion (including current maturities). The balance of Bonds outstanding directly affects TVA's capacity to meet operational liquidity needs and to strategically use Bonds to fund certain capital investments as management and the TVA Board may deem desirable.  Other options for financing not subject to the limit on Bonds, including lease financings, could provide supplementary funding if needed. Currently, TVA expects to utilize a combination of Bonds and additional power revenues through power rate increases to meet its ongoing operational liquidity needs while making planned capital investments through the decade. TVA may also utilize available federal funding through the Inflation Reduction Act of 2022 ("Inflation Reduction Act") and the Bipartisan Infrastructure Law ("BIL"), third party funding resources, or other funding sources. See Lease Financings below, Note 9 — Variable Interest Entities, and Note 12 — Debt and Other Obligations for additional information.

TVA may from time to time seek to retire or purchase its outstanding debt through cash purchases and/or exchanges for securities, in open market purchases, privately negotiated transactions, or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, TVA's liquidity requirements, contractual restrictions, and other factors. The amounts involved may be material.

Debt Securities.  TVA's Bonds are not obligations of the U.S., and the U.S. does not guarantee the payments of principal or interest on Bonds. TVA's Bonds consist of power bonds and discount notes. Power bonds have maturities of between one and 50 years. At December 31, 2023, the average maturity of long-term power bonds was 14.18 years, and the weighted average interest rate was 4.61 percent. Discount notes have maturities of less than one year. Power bonds and discount notes have a first priority and equal claim of payment out of net power proceeds. Net power proceeds are defined as the remainder of TVA's gross power revenues after deducting the costs of operating, maintaining, and administering its power properties and tax equivalents, but before deducting depreciation accruals or other charges representing the amortization of capital expenditures, plus the net proceeds from the sale or other disposition of any power facility or interest therein. In addition to power bonds and discount notes, TVA had long-term debt associated with certain VIEs outstanding at December 31, 2023. See Lease Financings below, Note 9 — Variable Interest Entities, and Note 12 — Debt and Other Obligations for additional information.

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The following table provides additional information regarding TVA's short-term borrowings:

Short-Term Borrowings (in millions)
	At December 31, 2023	Three Months Ended December 31, 2023	At December 31, 2022	Three Months Ended December 31, 2022
Gross Amount Outstanding (at End of Period) or Average Gross Amount Outstanding (During Period)
Discount notes	$1,043	$525	$1,620	$1,080
Maximum Month-End Gross Amount Outstanding (During Period)
Discount notes	N/A	$1,043	N/A	$1,620
Weighted Average Interest Rate
Discount notes	5.28%	5.41%	3.98%	3.58%

TVA's rated senior unsecured Bonds are currently rated Aaa, AA+, and AA+, by Moody's Investors Services, Inc. ("Moody's"), Fitch Ratings ("Fitch"), and Standard & Poor's Financial Services, LLC ("S&P"), respectively. TVA's short-term discount notes are not rated. TVA and the owners of TVA securities could be impacted by any downgrades of TVA's credit ratings. TVA Bonds are not obligations of the U.S.; however, because TVA is a wholly-owned corporate agency and instrumentality of the U.S. government, TVA's ratings may be impacted if the sovereign credit ratings of the U.S. are downgraded. In August 2023, Fitch downgraded the U.S. government's credit rating to AA+, reflecting its perception of a deterioration in the U.S. public finances and challenges associated with raising the U.S. debt limit. Fitch subsequently downgraded TVA's rating from AAA to AA+. TVA was not required to post additional collateral due to the downgrade. The outlook on the ratings of TVA is currently stable with S&P and Fitch. However, on November 10, 2023, Moody's revised the outlook on the U.S. government's credit ratings from stable to negative, and subsequently determined on November 13, 2023, to revise the outlook on TVA's ratings from stable to negative due to the change in the government rating outlook. TVA would not be required to post additional collateral if downgraded to Aa1 by Moody's. See Part I, Item 1A, Risk Factors — Financial, Economic, and Market Risks — TVA, together with owners of TVA securities, may be impacted by downgrades of TVA's credit ratings in the Annual Report.

According to statements made by the credit rating agencies, the U.S. rating may face additional downward pressure if policymakers are unable to respond to the country's growing fiscal challenges, if it appears deterioration in debt affordability or fiscal strength is likely to undermine U.S. economic strength or the role of the U.S. dollar or U.S. Treasury bond market, or if a weakening of governance were to occur. Additionally, TVA may be impacted by how the U.S. government addresses situations of approaching its debt limit. See Note 13 — Risk Management Activities and Derivative Transactions — Other Derivative Instruments — Collateral.

Lease Financings. TVA has entered into certain leasing transactions with special purpose entities ("SPEs") to obtain third-party financing for its facilities. These SPEs are sometimes identified as VIEs of which TVA is determined to be the primary beneficiary. TVA is required to account for these VIEs on a consolidated basis. See Note 9 — Variable Interest Entities.

Summary Cash Flows

A major source of TVA's liquidity is operating cash flows resulting from the generation and sale of electricity. Cash, cash equivalents, and restricted cash totaled $518 million and $520 million at December 31, 2023 and 2022, respectively. A summary of cash flow components for the three months ended December 31, 2023 and 2022, follows:

    Cash provided by (used in):

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Operating Activities. TVA's cash flows from operations are primarily driven by sales of electricity, fuel expense, and operating and maintenance expense. The timing and level of cash flows from operations can be affected by the weather, changes in working capital, commodity price fluctuations, outages, and other project expenses.

Net cash flows provided by operating activities decreased $46 million for the three months ended December 31, 2023, as compared to the same period of the prior year. Revenue collections decreased primarily due to lower fuel and purchased power prices which were partially offset by the base rate increase that began in 2024 and pandemic credits which ended in September 2023. There was also an increase in payroll and benefit related payments compared to the same period of the prior year. These decreases were partially offset by lower fuel and purchased power payments, a decrease in cash collateral payments made in the first quarter of 2023, and lower cash used for asset retirement obligation settlements.

Investing Activities. The majority of TVA's investing cash flows are due to investments to acquire, upgrade, or maintain generating and transmission assets, including environmental projects and the purchase of nuclear fuel.

Net cash flows used in investing activities increased $126 million for the three months ended December 31, 2023, as compared to the same period of the prior year, primarily driven by increased expenditures for capacity expansion projects partially offset by decreased expenditures for transmission projects and nuclear fuel during the period and the acquisition of leasehold interests in combustion turbine assets in the first quarter of 2023. Nuclear fuel expenditures vary depending on the number of outages and the prices and timing of purchases of uranium and enrichment services.

Financing Activities. TVA's cash flows provided by or used in financing activities are primarily driven by the timing and level of cash flows provided by operating activities, cash flows used in investing activities, and net issuance and redemption of debt instruments to maintain a strategic balance of cash on hand.

Net cash provided by financing activities increased $169 million for the three months ended December 31, 2023, as compared to the same period of the prior year, primarily due to higher net short-term debt issuances. Lower net cash flows provided by operating activities and higher net cash used in investing activities in the first quarter of 2024 resulted in the need for net short-term debt issuances to maintain targeted cash balance levels during the period. TVA may continue to have a need to increase debt in the coming years as it continues to invest in power system assets, which may result in positive net cash flows provided by financing activities in future periods.

    Contractual Obligations

TVA has certain obligations and commitments to make future payments under contracts. During the three months ended December 31, 2023, TVA entered into a purchase obligation for combustion turbine generators totaling $660 million of commitments from 2024 - 2027, of which $89 million is estimated to be paid during the remainder of 2024. TVA's contractual obligations are discussed in the Annual Report in Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources, Note 8 — Leases, Note 11 — Variable Interest Entities, Note 14 — Debt and Other Obligations, Note 20 — Benefit Plans, and Note 22 — Commitments and Contingencies.

Key Initiatives and Challenges

There have been no material changes to the key initiatives and challenges described in Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges of the Annual Report, except as described below.

Optimum Energy Portfolio

Coal-Fired Fleet. In 2023, TVA made available to the public a draft environmental impact statement ("EIS") to assess the impacts associated with the potential retirement of Kingston Fossil Plant and the construction and operation of facilities to replace that generation. As of December 31, 2023, TVA had spent $122 million on long lead time equipment in connection with this potential project. However, this equipment could be used at other TVA sites if the final project is not approved. TVA expects to publish a final EIS in the second quarter of 2024. See Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Coal-Fired Fleet in the Annual Report.

Natural Gas-Fired Units. As TVA continues to evaluate the impact of retiring its coal-fired fleet by 2035 and works to

accelerate the growth of renewables, it also continues to evaluate adding flexible lower carbon-emitting gas plants as a strategy

to maintain reliability. Pre-commercial plant operations began on Paradise Combustion Turbine Units 5-7 in the first quarter of 2024, and the units became operational on December 29, 2023, with a total summer net capability of 681 MW. See Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Natural Gas-Fired Units in the Annual Report. In addition, Allen Combustion Turbine Units 1-16, which accounted for 195 MW of summer net capability at September 30, 2023, were retired in December 2023. TVA is continuing to explore a 200 MW aeroderivative combustion turbine project at the Allen site.

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TVA is replacing generation for one unit at Cumberland Fossil Plant with a 1,450 MW combined cycle plant that is expected to be operational by CY 2026. As of December 31, 2023, TVA had spent $471 million on this project. See Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Natural Gas-Fired Units in the Annual Report.

Renewable Power Purchase Agreements. TVA issued a carbon-free request for proposal ("RFP") in July 2022, and in December 2023, TVA signed four power purchase agreements totaling over 600 MW of solar generation and 20 MW of battery storage capacity from the carbon-free RFP that are expected to come online by the end of CY 2028. See Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Renewable Power Purchase Agreements in the Annual Report.

Nuclear Fleet License Extensions. Subject to the completion of all appropriate environmental reviews, TVA is seeking to renew all nuclear generation units' licenses for an additional 20 years. The first license renewal application was submitted to the Nuclear Regulatory Commission in January 2024 for the three units at Browns Ferry Nuclear Plant following the completion of a Supplemental Environmental Impact Statement prepared by TVA to assess the environmental impacts associated with renewing the Browns Ferry Nuclear Plant licenses. See Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Nuclear Fleet License Extensions in the Annual Report.

Automated Energy Exchange Platform. The United States Court of Appeals for the District of Columbia Circuit ("D.C. Circuit") remanded the Federal Energy Regulatory Commission's ("FERC") approval of the Southeast Energy Exchange Market, sending the matter back to FERC for additional proceedings. FERC has yet to take any action on this matter, and on December 17, 2023, the petitioners filed another appeal on the theory that FERC's failure to act promptly after the D.C. Circuit's remand created a new appealable event. See Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Automated Energy Exchange Platform in the Annual Report.

Coal Combustion Residuals

Groundwater monitoring. TVA was involved in two lawsuits concerning the coal combustion residuals ("CCR") facilities at Gallatin Fossil Plant ("Gallatin"). One case was resolved by the entry of a consent order, under which TVA agreed to close the existing ash facility by removal, either to an on-site landfill or to an offsite facility. The removal plan and the Environmental Assessment Report ("EAR") were approved by Tennessee Department of Environment and Conservation ("TDEC") in 2023. TVA submitted the Gallatin Corrective Action/Risk Assessment ("CARA") Plan to TDEC in January 2024.

Corporate Governance

In December 2023, the TVA Board approved a revised committee structure under which the responsibilities of the Audit, Finance, Risk, and Cybersecurity Committee were separated into two new committees: the Audit, Risk, and Cybersecurity Committee and the Finance, Rates, and Portfolio Committee. Current members of the Audit, Risk, and Cybersecurity Committee are L. Michelle Moore (Chair), Beth P. Geer, and William J. Renick. Current members of the Finance, Rates, and Portfolio Committee are A. Wade White (Chair), Beth H. Harwell, and Joe H. Ritch. There were also additional membership changes to committees as follows: current members of the External Stakeholders and Regulation Committee are Beth Harwell (Chair), Beth P. Geer, and William J. Renick; current members of the Operations and Nuclear Oversight Committee are Robert P. Klein (Chair), L. Michelle Moore, and A. Wade White; and current members of the People and Governance Committee are Brian Noland (Chair), Beth Harwell, Robert P. Klein, and Joe H. Ritch.

The term of William B. Kilbride as member of the TVA Board ended January 3, 2024, with the adjournment of the most recent session of Congress. Although his term of office expired May 18, 2023, the TVA Act permitted him to continue to serve as Director until the end of this session of Congress.

Environmental Matters

There have been no material changes to the environmental matters described in Part I, Item 1, Business — Environmental Matters of the Annual Report, except as described below.

Water Quality Control Developments

Steam-Electric Effluent Guidelines. On January 8, 2021, TVA submitted requests to state regulatory authorities to modify National Pollutant Discharge Elimination System permits for Kingston Fossil Plant, Cumberland, Bull Run Fossil Plant, Shawnee Fossil Plant, and Gallatin to incorporate into the permits limitations in the Environmental Protection Agency's 2020 Effluent Limitation Guidelines rule. TDEC issued a final permit for Cumberland in the first quarter of 2024. See Part I, Item 1, Business — Environmental Matters — Water Quality Control Developments — Steam-Electric Effluent Guidelines in the Annual Report.

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Cleanup of Solid and Hazardous Wastes

Coal Combustion Residuals. In August 2015, TDEC issued an order that includes an iterative process through which TVA and TDEC will identify and evaluate any CCR contamination risks and, if necessary, respond to such risks. As part of this process, TVA has submitted EARs to TDEC, and after the EARs are approved, TVA will submit CARA Plans that will identify the unacceptable risks and TVA's proposed remediation. TDEC approved the EARs for John Sevier Fossil Plant and Cumberland in the first quarter of 2024. TVA submitted the John Sevier CARA Plan to TDEC in the first quarter of 2024 and expects to submit the Cumberland CARA Plan during the second quarter of 2024. See Part I, Item 1, Business — Environmental Matters — Cleanup of Solid and Hazardous Wastes — Coal Combustion Residuals in the Annual Report.

Legal Proceedings

From time to time, TVA is party to or otherwise involved in lawsuits, claims, proceedings, investigations, and other legal matters ("Legal Proceedings") that have arisen in the ordinary course of conducting its activities, as a result of catastrophic events or otherwise. As of December 31, 2023, TVA had accrued $28 million with respect to Legal Proceedings. No assurance can be given that TVA will not be subject to significant additional claims and liabilities. If actual liabilities significantly exceed the estimates made, TVA's results of operations, liquidity, and financial condition could be materially adversely affected.

For a discussion of certain current material Legal Proceedings, see Note 20 — Contingencies and Legal Proceedings — Legal Proceedings, which discussions are incorporated into this Part I, Item 2, Management's Discussion and Analysis of Financial Condition and Results of Operations.

Off-Balance Sheet Arrangements

At December 31, 2023, TVA had no off-balance sheet arrangements.

Critical Accounting Estimates

The preparation of financial statements requires TVA to estimate the effects of various matters that are inherently uncertain as of the date of the financial statements. Although the financial statements are prepared in conformity with accounting principles generally accepted in the U.S., TVA is required to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the amounts of revenues and expenses reported during the reporting period. Each of these estimates varies in regard to the level of judgment involved and its potential impact on TVA's financial results. Estimates are deemed critical either when a different estimate could have reasonably been used, or where changes in the estimate are reasonably likely to occur from period to period, and such use or change would materially impact TVA's financial condition, results of operations, or cash flows. TVA's critical accounting estimates and policies are discussed in Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Estimates and Note 1 — Summary of Significant Accounting Policies of the Notes to Consolidated Financial Statements in the Annual Report.

New Accounting Standards and Interpretations

For a discussion of new accounting standards and interpretations, see Note 2 — Impact of New Accounting Standards and Interpretations, which discussion is incorporated into this Part I, Item 2, Management's Discussion and Analysis of Financial Condition and Results of Operations.

Legislative and Regulatory Matters

For additional discussion on legislative and regulatory matters, including a discussion of environmental legislation and regulation, see Environmental Matters above. Also, see Part I, Item 1, Business — Environmental Matters and Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges of the Annual Report.

TVA does not engage, and does not control any entity that is engaged, in any activity listed under Section 13(r) of the Securities Exchange Act of 1934 ("Exchange Act"), which requires certain issuers to disclose certain activities relating to Iran involving the issuer and its affiliates.  Based on information supplied by each such person, none of TVA's directors and executive officers are involved in any such activities.  While TVA is an agency and instrumentality of the U.S., TVA does not believe its disclosure obligations, if any, under Section 13(r) extend to the activities of any other departments, divisions, or agencies of the U.S.

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ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There are no material changes related to market risks disclosed under Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Risk Management Activities in the Annual Report. See Note 13 — Risk Management Activities and Derivative Transactions for additional information regarding TVA's derivative transactions and risk management activities.

ITEM 4.  CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

TVA maintains disclosure controls and procedures designed to ensure that information required to be disclosed by TVA in reports that it files or submits under the Exchange Act is recorded, processed, summarized, and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms, and is accumulated and communicated to TVA’s management, as appropriate, to allow timely decisions regarding required disclosure. TVA's management, including the President and Chief Executive Officer, the Executive Vice President and Chief Financial and Strategy Officer, and members of the Disclosure Control Committee, including the Vice President and Controller (Principal Accounting Officer) (collectively "management"), evaluated the effectiveness of TVA's disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) as of December 31, 2023.  Based on this evaluation, management concluded that TVA's disclosure controls and procedures were effective as of December 31, 2023.

Changes in Internal Control over Financial Reporting

During the quarter ended December 31, 2023, there were no changes in TVA's internal control over financial reporting

that materially affected, or are reasonably likely to materially affect, TVA's internal control over financial reporting.

PART II - OTHER INFORMATION

ITEM 1.  LEGAL PROCEEDINGS

From time to time, TVA is party to or otherwise involved in lawsuits, claims, proceedings, investigations, and other legal matters ("Legal Proceedings") that have arisen in the ordinary course of conducting its activities, as a result of catastrophic events or otherwise.  While the outcome of the Legal Proceedings to which TVA is a party cannot be predicted with certainty, any adverse outcome to a Legal Proceeding involving TVA may have a material adverse effect on TVA's financial condition, results of operations, and cash flows.

For a discussion of certain current material Legal Proceedings, see Note 20 — Contingencies and Legal Proceedings — Legal Proceedings, which discussions are incorporated by reference into this Part II, Item 1, Legal Proceedings.

ITEM 1A.  RISK FACTORS

There are no material changes related to risk factors from the risk factors disclosed in Part I, Item 1A, Risk Factors in the Annual Report.

ITEM 5.  OTHER INFORMATION

Insider Trading Arrangements and Policies

During the three months ended December 31, 2023, no director or officer of TVA notified TVA of the adoption or termination of a "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement," as each term is defined in Item 408(a) of Regulation S-K.

Amended and Restated Executive Severance Plan

On January 26, 2024, the Chief Executive Officer amended and restated TVA's Executive Severance Plan to eliminate the additional benefits available to participants in connection with a change in control. A copy of the Amended and Restated Executive Severance Plan is attached as Exhibit 10.1 to this report and is incorporated herein by reference. The foregoing description is qualified in its entirety by reference to such document.

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ITEM 6.  EXHIBITS

Exhibit  No.	Description
3.1	Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (Incorporated by reference to Exhibit 3.1 to TVA's Quarterly Report on Form 10-Q for the quarter ended December 31, 2016, File No. 000-52313)
3.2	Bylaws of the Tennessee Valley Authority Adopted by the TVA Board of Directors on May 18, 2006, as amended on April 3, 2008, May 19, 2008, June 10, 2010, February 13, 2014, August 21, 2014, and November 6, 2014 (Incorporated by reference to Exhibit 3.2 to TVA's Annual Report on Form 10-K for the year ended September 30, 2014, File No. 000-52313)
10.1	Amended and Restated Executive Severance Plan Adopted as of January 26, 2024
31.1	Rule 13a-14(a)/15d-14(a) Certification Executed by the Chief Executive Officer
31.2	Rule 13a-14(a)/15d-14(a) Certification Executed by the Chief Financial Officer
32.1	Section 1350 Certification Executed by the Chief Executive Officer
32.2	Section 1350 Certification Executed by the Chief Financial Officer
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 Taxonomy Extension Schema
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase
101.LAB	Inline XBRL Taxonomy Extension Label Linkbase
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File - formatted in Inline XBRL and contained in Exhibit 101

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date:	January 29, 2024		TENNESSEE VALLEY AUTHORITY
			(Registrant)
		By:	/s/ Jeffrey J. Lyash
			Jeffrey J. Lyash
			President and Chief Executive Officer (Principal Executive Officer)
		By:	/s/ John M. Thomas, III
			John M. Thomas, III
			Executive Vice President and Chief Financial and Strategy Officer (Principal Financial Officer)

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EX-10.1

EXHIBIT 10.1

AMENDED AND RESTATED

EXECUTIVE SEVERANCE PLAN

Effective January 26, 2024

Prepared by: /s/ David Fountain          1/26/2024

David Fountain, EVP, General Counsel and         Date

Corporate Secretary

Amended and Restated January 26, 2024, to remove Change of Control-related provisions.

1. PURPOSE AND SCOPE	2
2. DEFINITIONS	2
2.1 “Beneficiary”	2
2.2 “Code”	3
2.3 “EAIP”	3
2.4 “Eligible Employee”	3
2.5 “Good Reason”	3
2.6 “Gross Misconduct”	4
2.7 “Level I Employee”	4
2.8 “Level II Employee”	4
2.9 “Level III Employee”	4
2.10 “LTIP”	5
2.11 “Participant”	5
2.12 “Plan”	5
2.13 “Section 409A”	5
2.14 “Separation from Service”	5
2.15 “Severance Multiple”	5
2.16 “Termination Date”	5
3. ELIGIBILITY AND PARTICIPATION	5
3.1 Eligibility	5
3.2 Participation	6
4. PLAN BENEFITS	6
4.1 Severance	6
4.2 Nonqualified Deferred Compensation Plans	6
4.3 Supplemental Executive Retirement Plan	6
4.4 No Duplication of Severance Benefits	6
5. PAYMENT OF SEVERANCE BENEFITS	6
5.1 In General	6
5.2 Benefits	7
6. PLAN ADMINISTRATION	8
6.1 Authority of Plan Administrator	8
6.2 Determinations by Plan Administrator	9
7. GENERAL PROVISIONS	9
7.1 Amendment or Termination of the Plan	9
7.2 Source of Payments	9

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7.3 Severability	9
7.4 Limitation of Rights	10
7.5 Titles	10
7.6 Governing Law	10
7.7 Claims and Appeals Procedures	11
7.8 Authorized Representatives	12
7.9 Compliance with Section 409A	12
7.10 Rehired Employees	14
7.11 Incapacity	14
7.12 Golden Parachute	14
7.13 Successors	15
7.14 Tax Withholding	16

Exhibits

1.PURPOSE AND SCOPE

Establishment. The Tennessee Valley Authority (“TVA” or the “Company”) hereby establishes this Executive Severance Plan (“Plan”). The Plan supports TVA’s compensation philosophy, which is designed to attract, retain, and engage employees needed to accomplish TVA’s broad mission.

Purpose. The purpose of the Plan is to provide a competitive severance payment (“Severance Payment”) to certain eligible employees in the event of a TVA-initiated separation for reasons other than Gross Misconduct, death, or disability or in the event an employee terminates his or her employment with TVA for Good Reason as defined below.

2.DEFINITIONS

Wherever used herein, the following terms have the meanings set forth below, unless a different meaning is clearly required by the context:

2.1     “Beneficiary” means a beneficiary designated in writing by a Participant to receive any payments to be made under the Plan to such Participant, and if no beneficiary is designated by the Participant, then the Participant’s estate shall be deemed to be the Participant’s designated beneficiary.

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2.2     “Code” means the Internal Revenue Code of 1986, as amended from time to time.

2.3     “EAIP” means TVA’s Executive Annual Incentive Plan, as amended from time to time.

2.4     “Eligible Employee” means any executive designated as a Level I Employee, Level II Employee, or Level III Employee, in each case as determined by the Plan Administrator from time to time, and each other person specifically designated as an Eligible Employee on the exhibits hereto.

2.5     “Good Reason” means the occurrence of any of the following:

(a)a material adverse change in the Participant’s authority, duties, or responsibilities (excluding during any period of Participant’s physical or mental incapacity) with respect to his or her employment with the Company without the Participant’s prior written consent;

(b)a material reduction in the Participant’s base salary without the Participant’s prior written consent (other than any reduction applicable to management employees generally);

(c)an actual change in the Participant’s principal work location by more than 50 miles and more than 50 miles from the Participant’s principal place of abode as of the date of such change in job location without the Participant’s prior written consent; or

(d)a material breach by the Company of any term or provision of the Plan without the Participant’s prior written consent.

A Participant may be considered to have such “Good Reason” to terminate employment for purposes of the Plan only if the Participant provides written notice to the Company of termination within 30 days of the occurrence of the applicable foregoing event(s) above or, if later, within 30 days of the date the Participant has knowledge that such event(s) occurred.

An event constituting Good Reason shall no longer constitute Good Reason if the circumstances described in the Good Reason notice are cured by the Company within 30 days following receipt of the Good

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Reason notice.  If the Company does not cure the circumstances giving rise to the Good Reason event described in the Good Reason notice within thirty (30) days after receipt of the Good Reason notice, the Participant who provided the Good Reason notice may resign for Good Reason by terminating employment within thirty (30) days following the end of the Company’s thirty (30) day cure period.

2.6     “Gross Misconduct” means:

(a)misconduct involving dishonesty, fraud, or gross negligence that directly results in significant economic or reputational harm to TVA;

(b)insubordination, intentional neglect of duties, or refusal to cooperate with investigations of TVA’s business practices;

(c)conviction of a crime amounting to a felony under the laws of the United States or any of the several states, or a crime of moral turpitude;

(d)a significant violation of TVA’s Code of Ethics or Code of Conduct; or

(e)disclosure without authorization of proprietary or confidential information of TVA.

The Plan Administrator shall determine in his, her, or its sole discretion whether the conduct of an employee constitutes Gross Misconduct.

2.7     “Level I Employee” means an executive serving as a Vice President or above whom the Plan Administrator does not designate as a Level II Employee, excluding the CEO and Level III Employees.

2.8     “Level II Employee” means an executive serving as a Vice President or above whom the Plan Administrator designates as a Level II Employee from time to time, excluding the CEO and Level III Employees.

2.9     “Level III Employee” means an Executive Vice President of the Company from time to time.

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2.10     “LTIP” means TVA’s Long-Term Incentive Plan, as amended from time to time.

2.11     “Participant” means any Eligible Employee whom the Plan Administrator designates as a Participant from time to time.

2.12     “Plan” means this Tennessee Valley Authority Executive Severance Plan as amended from time to time.

2.13     “Section 409A” means Section 409A of the Code, or any successor section under the Code, as amended and as interpreted by final or proposed regulations promulgated thereunder from time to time and by related guidance.

2.14     “Separation from Service” and like phrases have the meaning set forth in 26 C.F.R. §1.409A-1(h) as such provision may be amended from time to time.

2.15     “Severance Multiple” means, with respect to each Participant, the applicable Severance Multiple as set forth on the applicable exhibit hereto.

2.16 “Termination Date” means the date a Participant’s employment with TVA is terminated.

3.ELIGIBILITY AND PARTICIPATION

3.1     Eligibility. Eligibility to participate in the Plan shall be limited to employees who meet the following criteria:

3.1.1     Position and Designation.The Participant is an Eligible Employee whom the Plan Administrator has designated to participate in the Plan and has been notified of such designation.

3.1.2     Execution of Release. The Participant must execute a separation agreement and general release, which will include certain covenants such as confidentiality, non-compete, non-solicitation, non-disparagement, and cooperation, in form and substance reasonably satisfactory to TVA (the “Release”), that will be provided to the Participant prior to the effective date of the Participant’s Separation from Service (the “Termination Date”) or as soon as practicable following the Termination Date. A Participant may have up to 21 days (or such longer period as determined by the Plan Administrator) to consider the agreement before signing and may sign it at any time during such period. If the Participant signs the Release, he or she may cancel it within seven days. Any such cancellation must be in writing and signed by the Participant by close of business on the seventh calendar day after he or she signs

5

the Release. If the Participant does not cancel the agreement, the agreement will become effective on the eighth calendar day after the date of signature. If the Participant cancels the agreement, it will become null and void and TVA will not implement any of its terms.

3.2    Participation. A Participant may be eligible to receive Severance Payments following a Separation from Service due to (a) a termination of services by TVA (other than due to the Participant’s Gross Misconduct or as a result of the death or disability of the Participant); or (b) a resignation by the Participant due to Good Reason.

4.PLAN BENEFITS

4.1    Severance.A Participant who Separates from Service in accordance with Section 3.2 will be entitled to the benefits described in Section 5 or the applicable exhibit hereto, subject to the terms and conditions of payment otherwise set forth herein.

4.2     Nonqualified Deferred Compensation Plans.Each Participant shall be entitled to payment of his or her vested benefit, if any, under any nonqualified deferred compensation plan of TVA (including, but not limited to, the Deferred Compensation Plan) in accordance with the terms of such plan. For the avoidance of doubt, TVA is not modifying the terms of the Deferred Compensation Plan or any rights of Participants under such plan.

4.3     Supplemental Executive Retirement Plan.Each Participant shall be entitled to payment of his or her vested benefit, if any, under TVA’s Supplemental Executive Retirement Plan (“SERP”) in accordance with the terms of such plan.

4.4     No Duplication of Severance Benefits. The Plan is intended to replace any and all provisions providing for severance payments within each existing offer letter, employment agreement, and severance agreement between the Company and any Participant who receives Severance Payments. Accordingly, notwithstanding anything to the contrary in this Plan, a Participant who receives Severance Payments under the Plan will not be entitled to receive severance benefits under any other plan or agreement of the Company.

5.PAYMENT OF SEVERANCE BENEFITS

5.1     In General.Subject to the effectiveness of the Release and except as otherwise expressly set forth below, Severance Payments will be paid as a lump-sum payment as soon as practicable after (and in no event later

6

than sixty (60) days following) a Participant’s Separation from Service. This amount shall be paid in cash after deducting the amount of applicable federal, state, and local withholding taxes of any kind required by law to be withheld by TVA. In the event that the Participant dies before receiving a Severance Payment, the Severance Payment shall be paid to the Participant’s Beneficiary. All amounts will be approved by the Plan Administrator prior to payment.

5.2     Benefits.Each Participant who experiences a Separation from Service and otherwise meets the terms and conditions of the Plan shall be entitled to the following Severance Payments, in each case as determined by the Plan Administrator in good faith:

5.2.1     Cash Separation Payment. Severance equal to the product of (a) the applicable Severance Multiple times (b) sum of the Participant’s (i) annual base salary and (ii) target annual incentive amount with respect to the year in which the Termination Date occurs, with clauses (i) and (ii) measured in the aggregate as of the highest of, as applicable, (x) the Participant’s Termination Date or (y) the event(s) constituting Good Reason.

5.2.2     Continued Healthcare Benefits. Continued coverage for healthcare benefits following the Participant’s Separation from Service (at active employee rates with respect to the coverage levels in effect immediately prior to such Separation from Service) until the earlier of (a) the end of that number of months correlating with the applicable Severance Multiple times 12, or (b) the date upon which the Participant and/or the Participant’s eligible dependents become covered under similar plans (the “Continued Healthcare Benefits”). The Continued Healthcare Benefits will be made consistent with the applicable benefit plan(s) of the Company; provided, however, that in the Plan Administrator’s sole discretion, the Continued Healthcare Benefits may be administered through reimbursement in lieu of direct coverage, subject to the Company’s normal expense reimbursement policy, and will in either case be taxable to the extent required to avoid adverse consequences to Participant or the Company.

5.2.3     Unpaid Prior Year Incentive Awards. A lump sum cash payment equal to any EAIP award and/or LTIP award that has already vested at the time the Participant Separates from Service but has not yet been paid. For the avoidance of doubt, this payment is in lieu of any payments to which the Participant is entitled under the EAIP and/or the LTIP with respect to such EAIP and/or LTIP award.

5.2.4     In-Progress Annual Incentive Awards. A lump sum cash payment equal to any EAIP award the performance cycle of which is in

7

progress on the Termination Date, which shall be prorated and calculated based on target achievement and paid at such time as set forth in Section 5.1. For the avoidance of doubt, this payment shall be in lieu of any payment to which the Participant is entitled under the EAIP with respect to such EAIP award.

5.2.5     In-Progress Long-Term Incentive Award. If the Participant is eligible for Retirement (as defined in the LTIP), the Participant’s rights shall be unaffected and the Participant shall remain eligible for the benefits, if any, available to the Participant under the LTIP upon Separation from Service due to a Retirement.

6.PLAN ADMINISTRATION

6.1     Authority of Plan Administrator. The Plan shall be administered by the Chief Executive Officer (“CEO”) or designee (the “Plan Administrator”) unless otherwise delegated by the Board. For the avoidance of doubt, when the CEO is a Participant, the Plan Administrator shall be the Board or its designee. Subject to the express provisions of the Plan, the Plan Administrator shall have the power, authority, and sole and exclusive discretion to construe, interpret, and administer the Plan, including without limitation the power and authority to make factual determinations relating to, and correct mistakes in, payments and to take such other action in the administration and operation of the Plan as the Plan Administrator deems appropriate under the circumstances, including but not limited to the following:

8

6.1.1     The Plan Administrator may, from time to time, prescribe forms and procedures for carrying out the purposes and provisions of the Plan;

6.1.2     The Plan Administrator shall have the authority to prescribe the terms of any communications made under the Plan and to interpret and construe the Plan, any rules and regulations under the Plan, and the terms and conditions of any payment, and answer all questions arising under the Plan, including questions on the proper construction and interpretation of the Plan; and

6.1.3     To the extent permitted by law, the Plan Administrator may at any time delegate such powers and duties to one or more other executives or managers, whether ministerial or discretionary, as the Plan Administrator may deem appropriate, including but not limited to authorizing the Plan Administrator’s delegate to execute documents on the Plan Administrator’s behalf.

6.2     Determinations by Plan Administrator. All decisions, determinations, and interpretations by the Plan Administrator regarding the Plan, any rules and regulations under the Plan, and the terms and conditions of or operation of any Severance Payment shall be final and binding on all Participants.

7.GENERAL PROVISIONS

7.1     Amendment or Termination of the Plan. Subject to compliance with the requirements of Section 409A, the CEO or the Board, as appropriate, may amend or terminate the Plan at any time; provided, however, that neither the CEO nor the Board may amend or terminate the Plan except with the consent of any adversely affected Participant who has, prior thereto, experienced a Separation from Service.

7.2     Source of Payments.All Severance Payments shall be payable out of TVA’s general assets. Each Participant’s claim, if any, for payment shall not be superior to that of any general and unsecured creditor of TVA. Nothing contained in the Plan and no action taken pursuant to the provisions of the Plan shall create or be construed to create a trust of any kind or a fiduciary relationship between TVA and any Participant, Beneficiary, or other person. If an error or omission is discovered in any of the determinations, the Plan Administrator, in his, her, or its sole discretion, shall cause an appropriate equitable adjustment to be made in order to remedy such error or omission.

7.3     Severability. In the event that any provision or portion of the Plan shall be determined to be invalid or unenforceable for any reason, the

9

remaining provisions and portions of the Plan shall be unaffected thereby and shall remain in full force and effect to the fullest extent permitted by law.

7.4     Limitation of Rights. Nothing in the Plan shall be construed to give any employee any right to be selected as a Participant or to receive a Severance Payment or to be granted a Severance Payment other than as is provided in this document. Nothing in the Plan or any grant or payment issued pursuant to the Plan shall be construed to limit in any way the right of TVA to terminate a Participant’s employment at any time, without regard to the effect of such termination on any rights such Participant would otherwise have under the Plan, or give any right to a Participant to remain employed by TVA in any particular position or capacity or at any particular rate of remuneration. During the lifetime of the Participant, only the Participant (or the Participant’s legal representative) may exercise the rights and receive the benefits of any payment.

7.5     Titles. The titles of the articles and sections herein are included for convenience of reference only and shall not be construed as part of the Plan or have any effect upon the meaning of the provisions hereof. Unless the context requires otherwise, the singular shall include the plural and the masculine shall include the feminine. Words such as “herein,” “hereafter,” “hereof,” and “hereunder” shall refer to this instrument as a whole and not merely to the subdivision in which such words appear.

7.6     Governing Law. TVA is a corporate agency and instrumentality of the United States, and the Plan shall be governed by and construed under federal law. In the event federal law does not provide a rule of decision for any matter or issue under the Plan, the law of the State of Tennessee shall apply, without taking into account conflict of law principles. By participating in the Plan, each Participant agrees that the jurisdiction for any action with respect to the Plan shall lie in the United States District Court for the Eastern District of Tennessee.

10

7.7     Claims and Appeals Procedures.

7.7.1     Claims Procedure. Any Participant who feels he or she is entitled to Severance Payments must file a written claim with the Plan Administrator within 90 days following his or her Termination Date, on such applications or forms, if any, required by the Plan Administrator, for the claim to be valid. An initial determination shall be made by the Plan Administrator or such other persons as designated from time to time by the Board. Without limiting the foregoing, a request for Severance Payments will be considered a claim, and it will be subject to a full and fair review.

7.7.2     Denials. If a claim is wholly or partially denied, the Plan Administrator will provide the Participant with a written or electronic notification of the denial. This written or electronic notification will ordinarily be provided to the Participant no later than 90 days after the receipt of a claim by the Plan Administrator, unless the Plan Administrator determines that special circumstances require an extension of time for processing a claim. If the Plan Administrator determines that an extension of time for processing is required, written notice of the extension will be furnished to the Participant within the initial determination period or as soon as practicable thereafter.The Plan Administrator’s notification of a denial will generally provide the following information: (a) the reason or reasons for the denial; (b) an explanation of the basis on which the determination was made; (c)a description of any additional material or information necessary for a Participant to perfect the claim on appeal; and (d)information as to the steps to be taken if a Participant wants to appeal the denial of a claim.

7.7.3     Appeals Procedures. Upon the denial of a claim, a Participant may file an appeal, in writing, with the Plan Administrator in such form as may be designated by the Plan Administrator as follows: (a)a Participant must file an appeal no later than 60 days after the Participant has received written notification of the denial of the claim; (b) the Participant may submit written comments, documents, records, and other information relating to the appeal; (c) the Participant may review all pertinent documents relating to the denial of the claim and submit any issues and comments, in writing, to the Plan Administrator; (d)the Participant will be provided, upon request, with reasonable access to, and copies of, all documents, records, and other information relevant to the claim; and (e) the appeal will be given a full and fair review. This review will take into account comments, documents, records, and other information submitted by the Participant relating to the claim, without regard to whether such information was submitted or considered in the initial benefit determination.

11

7.7.4     Notifications. If the claim is approved on appeal, the Plan Administrator will notify the Participant accordingly. If the appeal is denied, the Plan Administrator will provide a notification that generally sets forth the following: (a) the specific reason or reasons for the denial; (b)an explanation of the basis on which the determination was made; and (c) a statement that the Participant is entitled to receive, upon request, reasonable access to, and copies of, all documents, records, and other information relevant to the claim. The Plan Administrator will ordinarily provide the Participant with written or electronic notification of the determination on appeal within 60 days after the receipt of the Participant’s notice of appeal, unless the Plan Administrator determines that special circumstances require an extension of time for processing the claim. If the Plan Administrator determines that an extension of time for processing is required, written notice of the extension will be furnished to the Participant prior to the termination of the initial 60-day period or as soon as practicable thereafter.

7.7.5     Further Review. A Participant is required to utilize and exhaust the claims and appeal procedures set forth in these procedures before filing a lawsuit. The scope of review by a court is limited to the administrative record developed as part of the claims and appeal procedures, and such review is further limited as to whether the determination by the Plan Administrator was arbitrary and capricious. Any lawsuit must be filed by the Participant no later than 30 calendar days from the date that the Plan Administrator sends written or electronic notification as required under Section 7.7.4.

7.7.6     Improper Payments. In the event that TVA approves a claim for Severance Payments, but later determines that a Participant engaged in Gross Misconduct, the Participant shall be required to return all Severance Payments received prior to TVA’s determination, and the Participant will no longer be entitled to receive any Severance Payments. TVA may enforce its rights under this Section by bringing a lawsuit in the venue specified in Section 7.6 at any time.

7.8     Authorized Representatives. Whenever TVA under the terms of the Plan is permitted or required to do or to perform any act or matter or thing, it shall be done and performed by a duly authorized representative of TVA.

7.9     Compliance with Section 409A. At all times, to the extent necessary to prevent the imposition of taxes and penalties under Section 409A, (a) the Plan shall be operated in accordance with the requirements of Section 409A; (b) any action that may be taken (and, to the extent possible, any action actually taken) by an authorized representative of

12

TVA and the Participants or their Beneficiaries shall not be taken (or shall be void and without effect), if such action violates the requirements of Section 409A; (c) any provision in the Plan that is determined to violate the requirements of Section 409A shall be void and without effect; and (d) any provision that is required by Section 409A to appear in the Plan that is not expressly set forth shall be deemed to be set forth herein, and the Plan shall be administered in all respects as if such provision were expressly set forth herein. TVA may at any time amend the Plan to cure any defect with respect to Section 409A but is not required to do so. No provision of the Plan is intended or shall be interpreted to create any right with respect to the tax treatment of the amounts paid hereunder, and TVA shall not, under any circumstances, have any liability to a Participant or Beneficiary for any taxes, penalties, or interest due on amounts paid or payable under the Plan, including taxes, penalties, or interest imposed under Section 409A. To the extent necessary to prevent the imposition of taxes and penalties under Section 409A, to the extent payments under the Plan could, due to the timing of a Release, be paid in either of two calendar years, such payments shall be paid in the later such calendar year.

For purposes of this Plan, all references to “termination of employment” and correlative phrases shall be construed to require a “separation from service” as defined under Section 409A. For purposes of applying the rules under Section 409A, each separately identifiable payment under this Plan shall be treated as a “separate payment,” within the meaning of Section 409A, and the right to a series of installment payments under this Plan is to be treated as a right to a series of “separate payments” under Section 409A. Notwithstanding anything to the contrary in the Plan, if TVA determines (a) that on the date the Participant’s employment with TVA terminates, the Participant is a “specified employee” (within the meaning of Section 409A) of TVA and (b) that any payments to be provided to the Participant pursuant to the Plan are or may become subject to the additional tax under Section 409A(a)(1)(B) or any other taxes or penalties imposed under Section 409A if provided at the time otherwise that would be required under the Plan, then such payments shall be delayed until the date that is six months after the date of the Participant’s “separation from service” (as such term is defined under Section 409A) with TVA, or, if earlier, the date of the Participant’s death. Any such delayed payments instead shall be made in a lump sum on the first day of the seventh month following the Participant’s “separation from service” (as such term is defined under Section 409A), or, if earlier, the date of the Participant’s death. To the extent that any expenses, reimbursement, fringe benefit, or other, similar plan or arrangement provides for a “deferral of compensation” within the meaning of Section 409A, then such amount shall be reimbursed in accordance with Section 409A, including (a) the

13

amount eligible for reimbursement or payment under such plan or arrangement in one calendar year may not affect the amount eligible for reimbursement or payment in any other calendar year (except that a plan providing medical or health benefits may impose a generally applicable limit on the amount that may be reimbursed or paid), (b) subject to any shorter time periods provided herein or the applicable plans or arrangements, any reimbursement or payment of an expense under such plan or arrangement must be made on or before the last day of the calendar year following the calendar year in which the expense was incurred, and (c) the right to any reimbursement or in-kind benefit is not subject to liquidation or exchange for another benefit.

7.10     Rehired Employees. Participants who experience a Separation from Service shall have no right to be re-employed by the Company. Each Participant’s right to receive or retain Severance Payments is conditioned upon such Participant not seeking or accepting re-employment from the Company without the written consent of the Plan Administrator. To the extent any Participant accepts re-employment with the Company in violation of this Section 7.10, the Company shall not be obligated to pay, and shall be entitled to the prompt repayment of, Severance Payments with respect to such Participant.

7.11     Incapacity. If a Participant or a Beneficiary experiences a mental incapacity or disability or is unable to care for his or her affairs because he or she is a minor, any payment or benefit due the Participant or Beneficiary may be paid or provided to the Participant’s spouse or to any other person deemed by the Plan Administrator to have incurred expense for such Participant (including a duly appointed guardian, committee, or other legal representative), and any such payment or provision of benefits shall be a complete discharge of the Company’s obligation hereunder.

7.12 Golden Parachute.

7.12.1 Anything in this Plan to the contrary notwithstanding, if any payment or benefit a Participant would receive from the Company or otherwise (“Payment”) would (a) constitute a “parachute payment” within the meaning of Section 280G of the Code, and (b) but for this sentence, be subject to the excise tax imposed by Section 4999 of the Code (the “Excise Tax”), then such Payment shall be equal to the Reduced Amount. The “Reduced Amount” shall be either (x) the largest portion of the Payment that would result in no portion of the Payment being subject to the Excise Tax, or (y) the largest portion, up to and including the total, of the Payment, whichever amount, after taking into account all applicable federal, state, and local employment taxes, income taxes, and the Excise Tax (all computed at the highest applicable marginal rate),

14

results in such Participant’s receipt, on an after-tax basis, of the greater amount of the Payment. Any reduction made pursuant to this Section 7.12.1 shall be made in accordance with the following order of priority: (i) Full Credit Payments (as defined below) that are payable in cash, (ii) non-cash Full Credit Payments that are taxable, (iii) non-cash Full Credit Payments that are not taxable, (iv) Partial Credit Payments (as defined below), and (v) non-cash employee welfare benefits. In each case, reductions shall be made in reverse chronological order such that the payment or benefit owed on the latest date following the occurrence of the event triggering the excise tax will be the first payment or benefit to be reduced (with reductions made pro-rata in the event payments or benefits are owed at the same time). “Full Credit Payment” means a payment, distribution, or benefit, whether paid or payable or distributed or distributable pursuant to the terms of this Plan or otherwise, that if reduced in value by one dollar reduces the amount of the parachute payment (as defined in Section 280G of the Code) by one dollar, determined as if such payment, distribution, or benefit had been paid or distributed on the date of the event triggering the excise tax. “Partial Credit Payment” means any payment, distribution, or benefit that is not a Full Credit Payment.

7.12.2 A nationally recognized certified public accounting firm selected by the Company (the “Accounting Firm”) shall perform the foregoing calculations related to the Excise Tax. If a reduction is required pursuant to Section 7.12.1, the Accounting Firm shall administer the ordering of the reduction as set forth in Section 7.12.1. The Company shall bear all expenses with respect to the determinations by such Accounting Firm required to be made hereunder.

7.12.3 The Accounting Firm engaged to make the determinations hereunder shall provide its calculations, together with detailed supporting documentation, to each affected Participant and the Company within fifteen (15) calendar days after the date on which each such Participant’s right to a Payment is triggered. Any good faith determinations of the Accounting Firm made hereunder shall be final, binding, and conclusive upon such Participant and the Company.

7.13     Successors. The Company shall assign its obligations under this Plan to any successor thereto, and any failure of the Company to obtain a satisfactory agreement from such successor to assume and agree to perform the obligations under this Plan shall constitute a material breach by the Company of this Plan.

15

7.14     Tax Withholding. TVA is authorized to withhold from any Severance Payment taxes due or potentially payable in connection with any transactions involving the Plan, and to take any other actions TVA may deem advisable to allow TVA to satisfy obligations for the payment of withholding taxes and other tax obligations related to any Severance Payment.

[Signature Page Follows]

16

IN WITNESS WHEREOF, this instrument has been executed this 26th day of January, 2024.

                        TENNESSEE VALLEY AUTHORITY

                        By:    /s/ Jeffrey J. Lyash

                            Jeffrey J. Lyash

                            President & Chief Executive Officer

17

Exhibit A

Benefits

This Exhibit A describes the payments offered to Participants in the TVA Executive Severance Plan (the “Plan”) upon a termination or resignation of employment with the Tennessee Valley Authority (the “Company”) as described in the Plan. Capitalized but undefined terms in this Exhibit A shall have the meanings set forth in the Plan.

The following description is intended only as a summary and is qualified in its entirety by reference to the full text of the Plan. In the event of any conflict between this summary and the Plan, the Plan shall control.

	Level I	Level II	Level III
Severance Multiple	0.5	0.5	1.0
Cash Separation Payment	Lump Sum: Severance Multiple * (Annual Salary + Target EAIP)
Healthcare Benefits	Continuation for up to Severance Multiple * 12 months
In-Progress EAIP	Prorated Actual	Prorated Actual	Prorated Actual
In-Progress LTIP	Forfeited	Forfeited	Forfeited

Exhibit B*

Benefits (CEO)

This Exhibit B describes the payments offered to the Chief Executive Officer (“CEO”) in the TVA Executive Severance Plan (the “Plan”) upon a termination or resignation of employment with the Tennessee Valley Authority (the “Company”) as described in the Plan. Capitalized but undefined terms in this Exhibit B shall have the meanings set forth in the Plan.

If the CEO (who, for the avoidance of doubt, is an Eligible Employee and a Participant) experiences a Separation from Service and otherwise meets the terms and conditions of the Plan, he or she shall be entitled to the following Severance Payments in accordance with the principles of Section 5 as if specifically set forth therein, in each case as determined by the Plan Administrator in good faith:

Severance Multiple	1.5
Cash Separation Payment	Lump Sum: Severance Multiple * (Annual Salary + Target EAIP)
Healthcare Benefits	Continuation for up to Severance Multiple * 12 months
In-Progress EAIP	Prorated Actual
In-Progress LTIP	Forfeited

* Approved by the TVA Board of Directors on February 11, 2021, and amended by the CEO on January 26, 2024, to remove Change-in-Control provisions.

EX-31.1

EXHIBIT 31.1

RULE 13a-14(a)/15d-14(a) CERTIFICATION

I, Jeffrey J. Lyash, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of the Tennessee Valley Authority;

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 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 we 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 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.

Date:	January 29, 2024	/s/ Jeffrey J. Lyash
		Jeffrey J. Lyash
		President and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

RULE 13a-14(a)/15d-14(a) CERTIFICATION

I, John M. Thomas, III, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of the Tennessee Valley Authority;

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 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 we 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 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.

Date:	January 29, 2024	/s/ John M. Thomas, III
		John M. Thomas, III
		Executive Vice President and Chief Financial and Strategy Officer
		(Principal Financial Officer)

EX-32.1

EXHIBIT 32.1

CERTIFICATION FURNISHED PURSUANT TO

SECURITIES EXCHANGE ACT RULE 13a-14(b)

 OR RULE 15d-14(b) AND 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of the Tennessee Valley Authority (the “Company”) for the quarter ended December 31, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jeffrey J. Lyash, President and Chief Executive Officer of the Company, certify, for the purposes of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934, as amended, and Section 1350 of Chapter 63 of Title 18 of the United States Code, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jeffrey J. Lyash

Jeffrey J. Lyash

President and Chief Executive Officer

January 29, 2024

EX-32.2

EXHIBIT 32.2

CERTIFICATION FURNISHED PURSUANT TO

SECURITIES EXCHANGE ACT RULE 13a-14(b)

 OR RULE 15d-14(b) AND 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of the Tennessee Valley Authority (the “Company”) for the quarter ended December 31, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John M. Thomas, III, Executive Vice President and Chief Financial and Strategy Officer of the Company, certify, for the purposes of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934, as amended, and Section 1350 of Chapter 63 of Title 18 of the United States Code, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ John M. Thomas, III

John M. Thomas, III

Executive Vice President and Chief Financial and Strategy Officer
(Principal Financial Officer)

January 29, 2024

XML

DEI Document shares in Millions	3 Months Ended
	Dec. 31, 2023 shares
DEI [Abstract]
Entity Registrant Name	TENNESSEE VALLEY AUTHORITY
Current Fiscal Year End Date	--09-30
Entity Address, Country	US
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Document Type	10-Q
Document Period End Date	Dec. 31, 2023
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding	0
Entity Current Reporting Status	Yes
Entity Shell Company	false
Document Quarterly Report	true
Local Phone Number	632-2101
City Area Code	(865)
Entity Tax Identification Number	62-0474417
Entity File Number	000-52313
Entity Address, Address Line One	400 W. Summit Hill Drive
Entity Address, City or Town	Knoxville
Entity Address, State or Province	TN
Entity Incorporation, State or Country Code	X1
Entity Address, Postal Zip Code	37902
Entity Interactive Data Current	Yes
Entity Central Index Key	0001376986
Entity Small Business	false
Document Transition Report	false
Document Information [Line Items]
Entity Incorporation, State or Country Code	X1

XML

CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Operating expenses
Fuel	$ 496	$ 615
Purchased power	359	491
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	867	827
Depreciation and amortization	521	533
Tax equivalents	133	151
Costs and Expenses	2,376	2,617
Operating income	389	398
Other income (expense), net	23	16
Defined Benefit Plan, Other Cost (Credit)	23	51
Interest expense
Interest expense	262	262
Net income (loss)	127	101
Regulated Operating Revenue	2,731	2,963
Unregulated Operating Revenue	34	52
Regulated and Unregulated Operating Revenue	$ 2,765	$ 3,015

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (UNAUDITED) - USD ($)	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Net income (loss)	$ 127,000,000	$ 101,000,000
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, after Tax	20,000,000	71,000,000
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, after Tax	19,000,000	34,000,000	[1]
Other comprehensive income (loss)
Total other comprehensive income (loss)	1,000,000	37,000,000
Total comprehensive income (loss)	$ 128,000,000	$ 138,000,000

[1] There were no amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $3 million of gains from Accumulated other comprehensive income (loss) ("AOCI") to Interest expense within the next 12 months to offset amounts anticipated to be recorded in Interest expense related to the forecasted exchange loss on the debt.

XML

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Current assets
Cash and cash equivalents	$ 498	$ 501
Accounts receivable, net	1,593	1,745
Inventories, net	1,182	1,108
Regulatory assets	251	178
Prepaid Expense and Other Assets, Current	152	134
Total current assets	3,676	3,666
Property, plant, and equipment
Completed plant	67,073	68,199
Less accumulated depreciation	(34,445)	(35,871)
Property, Plant, and Equipment, Owned, Net	32,628	32,328
Construction in progress	3,425	3,238
Nuclear fuel	1,364	1,344
Finance lease, asset	562	572
Total property, plant, and equipment, net	37,979	37,482
Investment funds	4,472	4,123
Regulatory and other long-term assets
Regulatory assets	5,551	5,566
Operating Lease, Right-of-Use Asset	258	177
Other long-term assets	312	330
Investments and Other Noncurrent Assets	6,121	6,073
Total assets	52,248	51,344
Current liabilities
Accounts payable and accrued liabilities	2,451	2,618
Accrued interest	268	272
Asset Retirement Obligation, Current	275	272
Regulatory liabilities	259	222
Short-term debt, net	1,042	432
Current maturities of power bonds	1,022	1,022
Current maturities of long-term debt of variable interest entities	35	35
Total current liabilities	5,352	4,873
Other liabilities
Post-retirement and post-employment benefit obligations	2,457	2,527
Asset retirement obligations	7,295	7,217
Finance Lease, Liability	571	576
Other long-term liabilities	1,488	1,211
Regulatory liabilities	103	107
Liabilities, Other than Long-Term Debt, Noncurrent	11,914	11,638
Long-term debt, net
Long-term power bonds, net	17,867	17,844
Long-term debt of variable interest entities, net	933	933
Total long-term debt, net	18,800	18,777
Total liabilities	36,066	35,288
Proprietary capital
Power program appropriation investment	258	258
Power program retained earnings	15,429	15,302
Total power program proprietary capital	15,687	15,560
Nonpower programs appropriation investment, net	523	525
Accumulated other comprehensive income (loss)	(28)	(29)
Total proprietary capital	16,182	16,056
Liabilities and Equity	$ 52,248	$ 51,344

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023		Dec. 31, 2022
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect [Abstract]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect	$ (3)		$ 0
Cash flows from operating activities
Net income (loss)	127		101
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation and amortization (including amortization of debt issuance costs and premiums/discounts)	527		538
Amortization of nuclear fuel cost	99		88
Non-cash retirement benefit expense	33		63
Amortization of Regulatory Asset	(46)		(69)
Changes in current assets and liabilities
Accounts receivable, net	153		256
Inventories and other current assets, net	(105)		(216)
Accounts payable and accrued liabilities	(289)		(86)
Accrued interest	(2)		(16)
Pension contributions	(75)		(75)
Other, net	(121)		(145)
Net cash provided by operating activities	393		439
Cash flows from investing activities
Construction expenditures	(863)		(605)
Nuclear fuel expenditures	(146)		(192)
Payments to Acquire Assets, Investing Activities	(1)		0
Acquisition of leasehold interests in combustion turbine assets	0		78
Loans and other receivables
Advances	(4)		0
Repayments	2		3
Other, net	10		(4)
Net cash used in investing activities	(1,002)		(876)
Long-term debt
Redemptions and repurchases of power bonds	(1)	[1]	(1)
Short-term debt issues (redemptions), net	610		446
Finance Lease, Principal Payments	10		10
Other, net	7		2
Net cash provided by (used in) financing activities	606		437
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	$ 518		$ 520

[1] (1) All redemptions were at 100 percent of par.

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CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL (UNAUDITED) - USD ($)	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2023	Sep. 30, 2022
Power Program Appropriation Investment	$ 258,000,000		$ 258,000,000
Power Program Retained Earnings	15,429,000,000		15,302,000,000
Nonpower Programs Appropriation Investment, Net	523,000,000		525,000,000
Accumulated Other Comprehensive Income (Loss) from Net Gains (Losses) on Cash Flow Hedges	(28,000,000)		(29,000,000)
Total Proprietary Capital	16,182,000,000	$ 15,642,000,000	16,056,000,000	$ 15,505,000,000
Net income (loss)	127,000,000	101,000,000
Total other comprehensive income (loss)	1,000,000	37,000,000
Return on power program appropriation investment	(2,000,000)	(1,000,000)
Power Program Appropriation Investment
Power Program Appropriation Investment	258,000,000	258,000,000	258,000,000	258,000,000
Net income (loss)	0	0
Total other comprehensive income (loss)	0	0
Return on power program appropriation investment	0	0
Power Program Retained Earnings
Power Program Retained Earnings	15,429,000,000	14,902,000,000	15,302,000,000	14,800,000,000
Net income (loss)	129,000,000	103,000,000
Total other comprehensive income (loss)	0	0
Return on power program appropriation investment	(2,000,000)	(1,000,000)
Nonpower Programs Appropriation Investment, Net
Nonpower Programs Appropriation Investment, Net	523,000,000	531,000,000	525,000,000	533,000,000
Net income (loss)	(2,000,000)	(2,000,000)
Total other comprehensive income (loss)	0	0
Return on power program appropriation investment	0	0
Accumulated Other Comprehensive Income (Loss) from Net Gains (Losses) on Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss) from Net Gains (Losses) on Cash Flow Hedges	(28,000,000)	(49,000,000)	$ (29,000,000)	$ (86,000,000)
Net income (loss)	0	0
Total other comprehensive income (loss)	1,000,000	37,000,000
Return on power program appropriation investment	$ 0	$ 0

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Supplemental Cash Flow Information Statement - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Other Significant Noncash Transactions [Line Items]
Capital Expenditures Incurred but Not yet Paid	$ 552	$ 363
Noncash or Part Noncash Acquisition, Payables Assumed	$ 46	$ 62

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Statement of Cash Flows, Supplemental Disclosures

3 Months Ended

Dec. 31, 2023

Supplemental Cash Flow Elements [Abstract]

Cash Flow, Supplemental Disclosures

Supplemental Cash Flow Information

Construction in progress and nuclear fuel expenditures included in Accounts payable and accrued liabilities at December 31, 2023 and 2022, were $552 million and $363 million, respectively, and are excluded from the Consolidated Statements of Cash Flows for the three months ended December 31, 2023 and 2022, as non-cash investing activities. ARO project accruals included in Accounts payable and accrued liabilities at December 31, 2023 and 2022 were $46 million and $62 million, respectively, and are excluded from the Consolidated Statements of Cash Flows for the three months ended December 31, 2023 and 2022, as non-cash operating activities.

Cash flows from swap contracts that are accounted for as hedges are classified in the same category as the item being

hedged or on a basis consistent with the nature of the instrument.

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Summary of Significant Accounting Policies (Text Block)

3 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Nature of Operations and Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Basis of Presentation

The Tennessee Valley Authority ("TVA") prepares its consolidated interim financial statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") for consolidated interim financial information. Accordingly, TVA's consolidated interim financial statements do not include all of the information and notes required by GAAP for annual financial statements. As such, they should be read in conjunction with the audited financial statements for the year ended September 30, 2023, and the notes thereto, which are contained in TVA's Annual Report on Form 10-K for the year ended September 30, 2023 (the "Annual Report"). In the opinion of management, all adjustments (consisting of items of a normal recurring nature) considered necessary for fair presentation are included on the consolidated interim financial statements.

The accompanying consolidated interim financial statements, which have been prepared in accordance with GAAP, include the accounts of TVA and variable interest entities ("VIEs") of which TVA is the primary beneficiary. See Note 9 — Variable Interest Entities. Intercompany balances and transactions have been eliminated in consolidation.

Fiscal Year

TVA's fiscal year ends September 30.  Years (2024, 2023, etc.) refer to TVA's fiscal years unless they are preceded by "CY," in which case the references are to calendar years.

Cash, Cash Equivalents, and Restricted Cash

Cash includes cash on hand, non-interest bearing cash, and deposit accounts. All highly liquid investments with original maturities of three months or less are considered cash equivalents. Cash and cash equivalents that are restricted, as to withdrawal or use under the terms of certain contractual agreements, are recorded in Other long-term assets on the Consolidated Balance Sheets. Restricted cash and cash equivalents include cash held in trusts that are currently restricted for TVA economic development loans and for certain TVA environmental programs in accordance with agreements related to compliance with certain environmental regulations.

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported on the Consolidated Balance Sheets and Consolidated Statements of Cash Flows:

Cash, Cash Equivalents, and Restricted Cash (in millions)
	At December 31, 2023		At September 30, 2023
Cash and cash equivalents	$	498	$	501
Restricted cash and cash equivalents included in Other long-term assets	20		20
Total cash, cash equivalents, and restricted cash	$	518	$	521

Allowance for Uncollectible Accounts

TVA recognizes an allowance that reflects the current estimate for credit losses expected to be incurred over the life of the financial assets based on historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amounts. The appropriateness of the allowance is evaluated at the end of each reporting period.

To determine the allowance for trade receivables, TVA considers historical experience and other currently available information, including events such as customer bankruptcy and/or a customer failing to fulfill payment arrangements by the due date. TVA's corporate credit department also performs an assessment of the financial condition of customers and the credit quality of the receivables. In addition, TVA reviews other reasonable and supportable forecasts to determine if the allowance for uncollectible amounts should be further adjusted in accordance with the accounting guidance for Current Expected Credit Losses.

To determine the allowance for loans receivables, TVA aggregates loans into the appropriate pools based on the existence of similar risk characteristics such as collateral types and internal assessed credit risks. In situations where a loan exhibits unique risk characteristics and is no longer expected to experience similar risks to the rest of its pool, the loan will be evaluated separately. TVA derives an annual loss rate based on historical loss and then adjusts the rate to reflect TVA's consideration of available information on current conditions and reasonable and supportable future forecasts. This information may include economic and business conditions, default trends, and other internal and external factors. For periods beyond the reasonable and supportable forecast period, TVA uses the current calculated long-term average historical loss rate for the remaining life of the loan portfolio.

The allowance for uncollectible accounts was less than $1 million at both December 31, 2023, and September 30, 2023, for trade accounts receivable. Additionally, loans receivable of $105 million and $104 million at December 31, 2023, and September 30, 2023, respectively, are included in Accounts receivable, net and Other long-term assets, for the current and long-term portions, respectively. Loans receivables are reported net of allowances for uncollectible accounts of $3 million at both December 31, 2023 and September 30, 2023.

Pre-Commercial Plant Operations

As part of the process of completing the construction of a generating unit, the electricity produced is used to serve the demands of the electric system. TVA estimates revenues earned during pre-commercial operations at the fair value of the energy delivered based on TVA's hourly incremental dispatch cost. Pre-commercial plant operations began on Paradise Combustion Turbine Units 5-7 in the first quarter of 2024, and the units became operational on December 29, 2023. Estimated revenue of $3 million related to this project was capitalized to offset project costs for the three months ended December 31, 2023. TVA also capitalized related fuel costs for this project of $3 million for the three months ended December 31, 2023.

Depreciation    

TVA accounts for depreciation of its properties using the composite depreciation convention of accounting. Under the composite method, assets with similar economic characteristics are grouped and depreciated as one asset. Depreciation is generally computed on a straight-line basis over the estimated service lives of the various classes of assets. The estimation of asset useful lives requires management judgment, supported by external depreciation studies of historical asset retirement experience. Depreciation rates are determined based on external depreciation studies that are updated approximately every five years, with the latest study implemented during the first quarter of 2022. Depreciation expense was $452 million and $466 million for the three months ended December 31, 2023 and 2022, respectively. See Note 6 — Plant Closures for a discussion of the impact of plant closures.

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Impact of New Accounting Standards and Interpretations (Text Block)

3 Months Ended

Dec. 31, 2023

Accounting Changes and Error Corrections [Abstract]

Accounting Standards Update and Change in Accounting Principle

Impact of New Accounting Standards and Interpretations     

The following are accounting standard updates issued by the Financial Accounting Standards Board that TVA adopted during 2024:

Accounting for Contract Assets and Contract Liabilities from Contracts with Customers
Description	This guidance requires an entity (acquirer) to recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with revenue with customers. It is expected that an acquirer will generally recognize and measure acquired contract assets and contract liabilities in a manner consistent with how the acquiree recognized and measured contract assets and contract liabilities in the acquiree’s financial statements. The entity should apply the standard prospectively to business combinations occurring on or after the effective date of the standard.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

Troubled Debt Restructurings and Vintage Disclosures
Description	This guidance eliminates the recognition and measurement guidance on troubled debt restructuring for creditors that have adopted Financial Instruments-Credit Losses and requires enhanced disclosures about loan modifications for borrowers experiencing financial difficulty. Additionally, the guidance requires public business entities to present current-period gross write-offs by year of origination in their vintage disclosures. The entity should apply the standard prospectively except for the transition method related to the recognition and measurement of troubled debt restructuring. For the transition method, an entity has the option to apply a modified retrospective transition method, resulting in a cumulative-effect adjustment to retained earnings in the period of adoption.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

The following accounting standard has been issued but as of December 31, 2023, was not effective and has not been adopted by TVA:

Improvements to Reportable Segment Disclosures
Description	This guidance improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The amendment requires a public entity to disclose, on an annual and interim basis, significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss. It also requires a public entity that has a single reportable segment to provide all of the disclosures required by the amendment and all existing segment disclosures. The amendment is effective for public entities for fiscal years beginning after December 15, 2023, and interim periods in fiscal years beginning after December 15, 2024. The amendment should be adopted retrospectively unless it is impracticable to do so. Upon adoption, a public entity will adopt the amendment as of the beginning of the earliest period presented.
Effective Date for TVA	October 1, 2024
Effect on the Financial Statements or Other Significant Matters	TVA is currently reviewing and evaluating this standard. TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations, or cash flows.

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Accounts Receivable, Net (Text Block)

3 Months Ended

Dec. 31, 2023

Accounts Receivable, after Allowance for Credit Loss [Abstract]

Accounts Receivable, Net

Accounts Receivable, Net

Accounts receivable primarily consist of amounts due from customers for power sales.  The table below summarizes the types and amounts of TVA's accounts receivable:

Accounts Receivable, Net (in millions)
	At December 31, 2023		At September 30, 2023
Power receivables	$	1,451	$	1,627
Other receivables	142		118
Accounts receivable, net(1)	$	1,593	$	1,745

Note

(1) Allowance for uncollectible accounts was less than $1 million at both December 31, 2023, and September 30, 2023, and therefore is not represented in the table above.

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Inventories, Net (Text Block)

3 Months Ended

Dec. 31, 2023

Inventory, Net [Abstract]

Inventories, Net

Inventories, Net

The table below summarizes the types and amounts of TVA's inventories:

Inventories, Net (in millions)
	At December 31, 2023		At September 30, 2023
Materials and supplies inventory	$	884	$	849
Fuel inventory	354		313
Renewable energy certificates/emissions allowance inventory, net	16		15
Allowance for inventory obsolescence	(72)		(69)
Inventories, net	$	1,182	$	1,108

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Deferred Costs, Capitalized, Prepaid, and Other Assets (Text Block)

3 Months Ended

Dec. 31, 2023

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Other Current Assets

Other Current Assets

Other current assets consisted of the following:

Other Current Assets  (in millions)
	At December 31, 2023		At September 30, 2023
Inventory work-in-progress	$	47	$	28
Prepaid software maintenance	36		18
Commodity contract derivative assets	19		21
Prepaid insurance	16		16
Current portion of prepaid long-term service agreements	10		25
Other	24		26
Other current assets	$	152	$	134

Commodity Contract Derivative Assets. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity as well as certain financial derivative contracts to hedge exposure to the price of natural gas. Commodity contract derivative assets classified as current include deliveries or settlements that will occur within 12 months or less. See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.

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Plant Closures (Text Block)

3 Months Ended

Dec. 31, 2023

Property, Plant and Equipment Impairment or Disposal [Abstract]

Plant Closures Disclosure

Plant Closures

Background

TVA must continuously evaluate all generating assets to ensure an optimal energy portfolio that provides safe, clean, and reliable power while maintaining flexibility and fiscal responsibility to the people of the Tennessee Valley. Based on results of assessments presented to the TVA Board of Directors ("TVA Board") in 2019, the retirement of Bull Run Fossil Plant ("Bull Run") by December 2023 was approved, and as of September 30, 2023, the facility was retired. In January 2023, TVA issued its Record of Decision to retire the two coal-fired units at Cumberland Fossil Plant ("Cumberland") by the end of CY 2026 and CY 2028. In addition, TVA is evaluating the impact of retiring the balance of the coal-fired fleet by 2035, and that evaluation includes environmental reviews, public input, and TVA Board approval.

Financial Impact

TVA's policy is to adjust depreciation rates to reflect the most current assumptions, ensuring units will be fully depreciated by the applicable retirement dates. As a result of TVA's decision to accelerate the retirement of Bull Run, TVA recognized a cumulative $659 million of accelerated depreciation from the second quarter of 2019 through September 30, 2023. Of this amount, $36 million was recognized for Bull Run during the three months ended December 31, 2022. TVA's decision to retire the two units at Cumberland is estimated to result in approximately $16 million of additional depreciation quarterly, which does not include any potential impact from additions or retirements to net completed plant. TVA estimates it has recognized a cumulative $64 million of additional depreciation since January 2023, related to this decision.

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Other Long-Term Assets (Text Block)

3 Months Ended

Dec. 31, 2023

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Other Long-Term Assets

Other Long-Term Assets

The table below summarizes the types and amounts of TVA's other long-term assets:

Other Long-Term Assets (in millions)
	At December 31, 2023		At September 30, 2023
Loans and other long-term receivables, net	$	101	$	97
EnergyRight® receivables, net	46		47
Prepaid long-term service agreements	44		64
Prepaid capital assets	21		28
Commodity contract derivative assets	12		12
Other	88		82
Total other long-term assets	$	312	$	330

Loans and Other Long-Term Receivables. TVA's loans and other long-term receivables primarily consist of economic development loans for qualifying organizations and a receivable for reimbursements to recover the cost of providing long-term, on-site storage for spent nuclear fuel. The current and long-term portions of the loans receivable are reported in Accounts receivable, net and Other long-term assets, respectively, on TVA's Consolidated Balance Sheets. At December 31, 2023 and September 30, 2023, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $4 million and $7 million, respectively.

EnergyRight® Receivables. In association with the EnergyRight® program, TVA's local power company customers ("LPCs") offer financing to end-use customers for the purchase of energy-efficient equipment. Depending on the nature of the energy-efficiency project, loans may have a maximum term of five years or 10 years. TVA purchases the resulting loans receivable from its LPCs. The loans receivable are then transferred to a third-party bank with which TVA has agreed to repay in full any loans receivable that have been in default for 180 days or more or that TVA has determined are uncollectible. Given this continuing involvement, TVA accounts for the transfer of the loans receivable as secured borrowings. The current and long-term portions of the loans receivable are reported in Accounts receivable, net and Other long-term assets, respectively, on TVA's Consolidated Balance Sheets. At December 31, 2023, and September 30, 2023, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $13 million and $12 million, respectively. See Note 10 — Other Long-Term Liabilities for information regarding the associated financing obligation.

Allowance for Loan Losses. The allowance for loan loss is an estimate of expected credit losses, measured over the estimated life of the loan receivables, that considers reasonable and supportable forecasts of future economic conditions in addition to information about historical experience and current conditions. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts.

The allowance components, which consist of a collective allowance and specific loans allowance, are based on the risk characteristics of TVA's loans. Loans that share similar risk characteristics are evaluated on a collective basis in measuring credit losses, while loans that do not share similar risk characteristics with other loans are evaluated on an individual basis.

Allowance Components (in millions)
	At December 31, 2023		At September 30, 2023
EnergyRight® loan reserve	$	1	$	1
Economic development loan collective reserve	1		1
Economic development loan specific loan reserve	1		1
Total allowance for loan losses	$	3	$	3

Prepaid Long-Term Service Agreements. TVA has entered into various long-term service agreements for major maintenance activities at certain of its combined cycle plants. TVA uses the direct expense method of accounting for these arrangements. TVA accrues for parts when it takes ownership and for contractor services when they are rendered. Under certain of these agreements, payments made exceed the value of parts received and services rendered. The current and long-term portions of the resulting prepayments are reported in Other current assets and Other long-term assets, respectively, on TVA's Consolidated Balance Sheets. At December 31, 2023, and September 30, 2023, prepayments of $10 million and $25 million, respectively, were recorded in Other current assets.

Commodity Contract Derivative Assets. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity as well as certain financial derivative contracts to hedge exposure to the

price of natural gas. See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.

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Regulatory Assets and Liabilities

3 Months Ended

Dec. 31, 2023

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

8.  Regulatory Assets and Liabilities

TVA records certain assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for non-regulated entities. As such, certain items that would generally be reported in earnings or that would impact the Consolidated Statements of Operations are recorded as regulatory assets or regulatory liabilities. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates.  Regulatory liabilities generally represent obligations to make refunds to customers for previous collections for costs that are not likely to be incurred or deferral of gains that will be credited to customers in future periods. Components of regulatory assets and regulatory liabilities are summarized in the table below.

Regulatory Assets and Liabilities (in millions)
	At December 31, 2023		At September 30, 2023
Current regulatory assets
Unrealized losses on interest rate derivatives	$	37	$	31
Unrealized losses on commodity derivatives	213		136
Fuel cost adjustment receivable	—		11
Other current regulatory assets	1		—
Total current regulatory assets	251		178
Non-current regulatory assets
Retirement benefit plans deferred costs	1,438		1,440
Non-nuclear decommissioning costs	2,838		2,922
Unrealized losses on interest rate derivatives	459		272
Nuclear decommissioning costs	543		728
Unrealized losses on commodity derivatives	98		52
Other non-current regulatory assets	175		152
Total non-current regulatory assets	5,551		5,566
Total regulatory assets	$	5,802	$	5,744
Current regulatory liabilities
Fuel cost adjustment tax equivalents	$	190	$	201
Fuel cost adjustment	50		—
Unrealized gains on commodity derivatives	19		21
Total current regulatory liabilities	259		222
Non-current regulatory liabilities
Retirement benefit plans deferred credits	91		95
Unrealized gains on commodity derivatives	12		12
Total non-current regulatory liabilities	103		107
Total regulatory liabilities	$	362	$	329

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Variable Interest Entities

3 Months Ended

Dec. 31, 2023

Text Block [Abstract]

Variable Interest Entity Disclosure

Variable Interest Entities

A VIE is an entity that either (i) has insufficient equity to permit the entity to finance its activities without additional subordinated financial support or (ii) has equity investors who lack the characteristics of owning a controlling financial interest. When TVA determines that it has a variable interest in a VIE, a qualitative evaluation is performed to assess which interest holders have the power to direct the activities that most significantly impact the economic performance of the entity and have the obligation to absorb losses or receive benefits that could be significant to the entity. The evaluation considers the purpose and

design of the business, the risks that the business was designed to create and pass along to other entities, the activities of the business that can be directed and which party can direct them, and the expected relative impact of those activities on the economic performance of the business through its life. TVA has the power to direct the activities of an entity when it has the ability to make key operating and financing decisions, including, but not limited to, capital investment and the issuance of debt. Based on the evaluation of these criteria, TVA has determined it is the primary beneficiary of certain entities and as such is required to account for the VIEs on a consolidated basis.

John Sevier VIEs

In 2012, TVA entered into a $1.0 billion construction management agreement and lease financing arrangement with John Sevier Combined Cycle Generation LLC ("JSCCG") for the completion and lease by TVA of the John Sevier Combined Cycle Facility ("John Sevier CCF"). JSCCG is a special single-purpose limited liability company formed in January 2012 to finance the John Sevier CCF through a $900 million secured note issuance (the "JSCCG notes") and the issuance of $100 million of membership interests subject to mandatory redemption.  The membership interests were purchased by John Sevier Holdco LLC ("Holdco").  Holdco is a special single-purpose entity, also formed in January 2012, established to acquire and hold the membership interests in JSCCG.  A non-controlling interest in Holdco is held by a third party through nominal membership interests, to which none of the income, expenses, and cash flows are allocated. 

The membership interests held by Holdco in JSCCG were purchased with proceeds from the issuance of $100 million of secured notes (the "Holdco notes") and are subject to mandatory redemption pursuant to a schedule of amortizing, semi-annual payments due each January 15 and July 15, with a final payment due in January 2042. The payment dates for the mandatorily redeemable membership interests are the same as those of the Holdco notes. The sale of the JSCCG notes, the membership interests in JSCCG, and the Holdco notes closed in January 2012. The JSCCG notes are secured by TVA's lease payments, and the Holdco notes are secured by Holdco's investment in, and amounts receivable from, JSCCG. TVA's lease payments to JSCCG are equal to and payable on the same dates as JSCCG's and Holdco's semi-annual debt service payments. In addition to the lease payments, TVA pays administrative and miscellaneous expenses incurred by JSCCG and Holdco. Certain agreements related to this transaction contain default and acceleration provisions.

Due to its participation in the design, business activity, and credit and financial support of JSCCG and Holdco, TVA has determined that it has a variable interest in each of these entities. Based on its analysis, TVA has concluded that it is the primary beneficiary of JSCCG and Holdco and, as such, is required to account for the VIEs on a consolidated basis. Holdco's membership interests in JSCCG are eliminated in consolidation.

Southaven VIE

In 2013, TVA entered into a $400 million lease financing arrangement with Southaven Combined Cycle Generation LLC ("SCCG") for the lease by TVA of the Southaven Combined Cycle Facility ("Southaven CCF"). SCCG is a special single-purpose limited liability company formed in June 2013 to finance the Southaven CCF through a $360 million secured notes issuance (the "SCCG notes") and the issuance of $40 million of membership interests subject to mandatory redemption. The membership interests were purchased by Southaven Holdco LLC ("SHLLC"). SHLLC is a special single-purpose entity, also formed in June 2013, established to acquire and hold the membership interests in SCCG. A non-controlling interest in SHLLC is held by a third party through nominal membership interests, to which none of the income, expenses, and cash flows of SHLLC are allocated.

The membership interests held by SHLLC were purchased with proceeds from the issuance of $40 million of secured notes (the "SHLLC notes") and are subject to mandatory redemption pursuant to a schedule of amortizing, semi-annual payments due each February 15 and August 15, with a final payment due on August 15, 2033. The payment dates for the mandatorily redeemable membership interests are the same as those of the SHLLC notes, and the payment amounts are sufficient to provide returns on, as well as returns of, capital until the investment has been repaid to SHLLC in full. The rate of return on investment to SHLLC is seven percent, which is reflected as interest expense in the Consolidated Statements of Operations. SHLLC is required to pay a pre-determined portion of the return on investment to Seven States Southaven, LLC on each lease payment date as agreed in SHLLC's formation documents (the "Seven States Return"). The current and long-term portions of the Membership interests of VIE subject to mandatory redemption are included in Accounts payable and accrued liabilities and Other long-term liabilities, respectively.

The payment dates for the mandatorily redeemable membership interests are the same as those of the SHLLC notes. The SCCG notes are secured by TVA's lease payments, and the SHLLC notes are secured by SHLLC's investment in, and amounts receivable from, SCCG. TVA's lease payments to SCCG are payable on the same dates as SCCG's and SHLLC's semi-annual debt service payments and are equal to the sum of (i) the amount of SCCG's semi-annual debt service payments, (ii) the amount of SHLLC's semi-annual debt service payments, and (iii) the amount of the Seven States Return. In addition to the lease payments, TVA pays administrative and miscellaneous expenses incurred by SCCG and SHLLC. Certain agreements related to this transaction contain default and acceleration provisions.

In the event that TVA were to choose to exercise an early buy out feature of the Southaven facility lease, in part or in whole, TVA must pay to SCCG amounts sufficient for SCCG to repay or partially repay on a pro rata basis the membership interests held by SHLLC, including any outstanding investment amount plus accrued but unpaid return. TVA also has the right, at

any time and without any early redemption of the other portions of the Southaven facility lease payments due to SCCG, to fully repay SHLLC's investment, upon which repayment SHLLC will transfer the membership interests to a designee of TVA.

TVA participated in the design, business activity, and financial support of SCCG and has determined that it has a direct variable interest in SCCG resulting from risk associated with the value of the Southaven CCF at the end of the lease term. Based on its analysis, TVA has determined that it is the primary beneficiary of SCCG and, as such, is required to account for the VIE on a consolidated basis.

Impact on Consolidated Financial Statements

The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG at December 31, 2023, and September 30, 2023, as reflected on the Consolidated Balance Sheets, are as follows:

Summary of Impact of VIEs on Consolidated Balance Sheets (in millions)
	At December 31, 2023		At September 30, 2023
Current liabilities
Accrued interest	$	21	$	9
Accounts payable and accrued liabilities	1		1
Current maturities of long-term debt of variable interest entities	35		35
Total current liabilities	57		45
Other liabilities
Other long-term liabilities	17		17
Long-term debt, net
Long-term debt of variable interest entities, net	933		933
Total liabilities	$	1,007	$	995

Interest expense of $12 million for both the three months ended December 31, 2023 and 2022, is included in the Consolidated Statements of Operations related to debt of VIEs and membership interests of VIEs subject to mandatory redemption.

Creditors of the VIEs do not have any recourse to the general credit of TVA. TVA does not have any obligations to provide financial support to the VIEs other than as prescribed in the terms of the agreements related to these transactions.

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Other Long-Term Liabilities

3 Months Ended

Dec. 31, 2023

Other Liabilities, Noncurrent [Abstract]

Other Long-Term Liabilities

Other Long-Term Liabilities

Other long-term liabilities consist primarily of liabilities related to certain derivative agreements as well as liabilities related to operating leases. The table below summarizes the types and amounts of Other long-term liabilities:

Other Long-Term Liabilities (in millions)
	At December 31, 2023		At September 30, 2023
Interest rate swap liabilities	$	782	$	627
Operating lease liabilities	163		93
Currency swap liabilities	112		131
Commodity contract derivative liabilities	98		52
EnergyRight® financing obligation	55		55
Advances for construction	46		56
Long-term deferred revenue	46		45
Long-term deferred compensation	32		41
Other	154		111
Total other long-term liabilities	$	1,488	$	1,211

Interest Rate Swap Liabilities. TVA uses interest rate swaps to fix variable short-term debt to a fixed rate. The values of these derivatives are included in Other current assets, Accounts payable and accrued liabilities, Accrued interest, and Other long-term liabilities on the Consolidated Balance Sheets. See Note 13 — Risk Management Activities and Derivative

Transactions — Overview of Accounting Treatment and Derivatives Not Receiving Hedge Accounting Treatment — Interest Rate Derivatives for information regarding the interest rate swap liabilities.

Operating Lease Liabilities. TVA's operating leases consist primarily of railcars, equipment, real estate/land, and power generating facilities. At December 31, 2023, and September 30, 2023, the current portion of TVA's operating leases reported in Accounts payable and accrued liabilities was $81 million and $71 million, respectively.

Currency Swap Liabilities. To protect against exchange rate risk related to British pound sterling denominated Bond transactions, TVA entered into foreign currency hedges. The values of these derivatives are included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. See Note 13 — Risk Management Activities and Derivative Transactions — Overview of Accounting Treatment and Cash Flow Hedging Strategy for Currency Swaps for more information regarding the currency swap liabilities.

Commodity Contract Derivative Liabilities. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity as well as certain financial derivative contracts to hedge exposure to the price of natural gas. See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.

EnergyRight® Financing Obligation. TVA purchases certain loans receivable from its LPCs in association with the EnergyRight® program. The current and long-term portions of the resulting financing obligation are reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA's Consolidated Balance Sheets. At both December 31, 2023, and September 30, 2023, the carrying amount of the financing obligation reported in Accounts payable and accrued liabilities was $14 million. See Note 7 — Other Long-Term Assets for information regarding the associated loans receivable.

Long-Term Deferred Compensation. TVA provides compensation arrangements to engage and retain certain employees, both executive and non-executive, which are designed to provide participants with the ability to defer compensation to future periods. The current and long-term portions are recorded in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA’s Consolidated Balance Sheets. At December 31, 2023 and September 30, 2023, the current amount of deferred compensation recorded in Accounts payable and accrued liabilities was $32 million and $65 million, respectively.

Advances for Construction. TVA receives refundable and non-refundable advances for construction that are generally intended to defray all or a portion of the costs of building or extending TVA’s existing power assets. Amounts received are deferred as a liability with the long-term portion representing amounts that will not be recognized within the next 12 months. As projects meet milestones or other contractual obligations, the refundable portion is refunded to the customer and the non-refundable portion is recognized as contributions in aid of construction and offsets the cost of plant assets. At December 31, 2023 and September 30, 2023, the current amount of advances for construction recorded in Accounts payable and accrued liabilities was $60 million and $39 million, respectively.

Long-Term Deferred Revenue. Long-term deferred revenue represents payments received that exceed services rendered resulting in the deferral of revenue. The long-term portion represents amounts that will not be recognized within the next 12 months primarily related to fiber and transmission agreements. The current and long-term portions of the deferral are reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA’s Consolidated Balance Sheets. At December 31, 2023 and September 30, 2023, the current amount of deferred revenue recorded in Accounts payable and accrued liabilities was $23 million and $21 million, respectively.

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Asset Retirement Obligations

3 Months Ended

Dec. 31, 2023

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

During the three months ended December 31, 2023, TVA's total asset retirement obligations ("ARO") liability increased $81 million as a result of revisions in estimate and periodic accretion, partially offset by settlements related to retirement projects that were conducted during the period. The nuclear and non-nuclear accretion amounts were deferred as regulatory assets.  During the three months ended December 31, 2023, $47 million of the related regulatory assets were amortized into expense as these amounts were collected in rates. See Note 8 — Regulatory Assets and Liabilities. TVA maintains investment trusts to help fund its decommissioning obligations. See Note 14 — Fair Value Measurements — Investment Funds and Note 20 — Contingencies and Legal Proceedings — Contingencies — Decommissioning Costs for a discussion of the trusts' objectives and the current balances of the trusts.

Asset Retirement Obligation Activity (in millions)
	Nuclear		Non-Nuclear		Total
Balance at September 30, 2023	$	3,808	$	3,681	$	7,489	(1)
Settlements	(4)		(59)		(63)
Revisions in estimate	—		78		78
Accretion (recorded as regulatory asset)	43		23		66
Balance at December 31, 2023	$	3,847	$	3,723	$	7,570	(1)

Note

(1) Includes $275 million and $272 million at December 31, 2023, and September 30, 2023, respectively, in Current liabilities.

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Debt and Other Obligations

3 Months Ended

Dec. 31, 2023

Debt Disclosure [Abstract]

Debt and Other Obligations

Debt and Other Obligations

Debt Outstanding

Total debt outstanding at December 31, 2023, and September 30, 2023, consisted of the following:

Debt Outstanding  (in millions)
	At December 31, 2023		At September 30, 2023
Short-term debt
Short-term debt, net of discounts	$	1,042	$	432
Current maturities of power bonds issued at par	1,022		1,022
Current maturities of long-term debt of VIEs issued at par	35		35
Total current debt outstanding, net	2,099		1,489
Long-term debt
Long-term power bonds(1)	17,990		17,970
Long-term debt of VIEs, net	933		933
Unamortized discounts, premiums, issue costs, and other	(123)		(126)
Total long-term debt, net	18,800		18,777
Total debt outstanding	$	20,899	$	20,266

Note

(1) Includes total net exchange gain from currency transactions of $88 million and $109 million at December 31, 2023, and September 30, 2023, respectively.

Debt Securities Activity

The table below summarizes the long-term debt securities activity for the period from October 1, 2023, to December 31, 2023:

Debt Securities Activity
	Date	Amount (in millions)
Redemptions/Maturities(1)
2009 Series B	December 2023	$	1
Total redemptions/maturities of debt		$	1

Note

(1) All redemptions were at 100 percent of par.

Credit Facility Agreements

TVA has funding available under four long-term revolving credit facilities totaling $2.7 billion. See the table below for additional information on the four long-term revolving credit facilities. The interest rate on any borrowing under these facilities varies based on market factors and the rating of TVA's senior unsecured, long-term, non-credit-enhanced debt. TVA is required to pay an unused facility fee on the portion of the total $2.7 billion that TVA has not borrowed or committed under letters of credit.

This fee, along with letter of credit fees, may fluctuate depending on the rating of TVA's senior unsecured, long-term, non-credit-enhanced debt. At December 31, 2023, and September 30, 2023, there were $469 million and $535 million, respectively, of letters of credit outstanding under these facilities, and there were no borrowings outstanding. TVA's letters of credit are primarily posted as collateral under TVA's interest rate swaps. See Note 13 — Risk Management Activities and Derivative Transactions — Other Derivative Instruments — Collateral. TVA may also post collateral for TVA's currency swaps, for commodity derivatives under the Financial Hedging Program ("FHP"), or for certain transactions with third parties that require TVA to post letters of credit.

The following table provides additional information regarding TVA's funding available under the four long-term revolving credit facilities:

Summary of Long-Term Credit Facilities At December 31, 2023 (in millions)
Maturity Date	Facility Limit		Letters of Credit Outstanding		Cash Borrowings		Availability
February 2025	$	500	$	223	$	—	$	277
March 2026	150		38		—		112
September 2026	1,000		112		—		888
March 2027	1,000		96		—		904
Total	$	2,650	$	469	$	—	$	2,181

TVA and the United States ("U.S.") Department of the Treasury ("U.S. Treasury"), pursuant to the Tennessee Valley Authority Act of 1933, as amended ("TVA Act"), have entered into a memorandum of understanding under which the U.S. Treasury provides TVA with a $150 million credit facility. This credit facility was renewed for 2024 with a maturity date of September 30, 2024. Access to this credit facility or other similar financing arrangements with the U.S. Treasury has been available to TVA since the 1960s. TVA can borrow under the U.S. Treasury credit facility only if it cannot issue bonds, notes, or other evidences of indebtedness (collectively, "Bonds") in the market on reasonable terms, and TVA considers the U.S. Treasury credit facility a secondary source of liquidity. The interest rate on any borrowing under this facility is based on the average rate on outstanding marketable obligations of the U.S. with maturities from date of issue of 12 months or less. There were no outstanding borrowings under the facility at December 31, 2023. The availability of this credit facility may be impacted by how the U.S. government addresses the possibility of approaching its debt limit.

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Risk Management Activities and Derivative Transactions

3 Months Ended

Dec. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Risk Management Activities and Derivative Transactions

Risk Management Activities and Derivative Transactions

TVA is exposed to various risks related to commodity prices, investment prices, interest rates, currency exchange rates, and inflation as well as counterparty credit and performance risks.  To help manage certain of these risks, TVA has historically entered into various derivative transactions, principally commodity option contracts, forward contracts, swaps, swaptions, futures, and options on futures.  

Overview of Accounting Treatment

TVA recognizes certain of its derivative instruments as either assets or liabilities on its Consolidated Balance Sheets at fair value.  The accounting for changes in the fair value of these instruments depends on (1) whether TVA uses regulatory accounting to defer the derivative gains and losses, (2) whether the derivative instrument has been designated and qualifies for hedge accounting treatment, and (3) if so, the type of hedge relationship (for example, cash flow hedge).

The following tables summarize the accounting treatment that certain of TVA's financial derivative transactions receive:

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 1)  Amount of Mark-to-Market Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) (in millions)
			Three Months Ended December 31
Derivatives in Cash Flow Hedging Relationship	Objective of Hedge Transaction	Accounting for Derivative Hedging Instrument	2023		2022
Currency swaps	To protect against changes in cash flows caused by changes in foreign currency exchange rates (exchange rate risk)	Unrealized gains and losses are recorded in AOCI and reclassified to Interest expense to the extent they are offset by gains and losses on the hedged transaction	$	20	$	71

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2)(1) Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Interest Expense (in millions)
	Three Months Ended December 31
Derivatives in Cash Flow Hedging Relationship	2023		2022
Currency swaps	$	19	$	34

Note

(1) There were no amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $3 million of gains from Accumulated other comprehensive income (loss) ("AOCI") to Interest expense within the next 12 months to offset amounts anticipated to be recorded in Interest expense related to the forecasted exchange loss on the debt.

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment Amount of Gain (Loss) Recognized in Income on Derivatives(1) (in millions)
			Three Months Ended December 31
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2023		2022
Interest rate swaps	To fix short-term debt variable rate to a fixed rate (interest rate risk)	Mark-to-market gains and losses are recorded as regulatory liabilities and assets, respectively Realized gains and losses are recognized in Interest expense when incurred during the settlement period and are presented in operating cash flow	$	(8)	$	(15)
Commodity derivatives under the FHP	To protect against fluctuations in market prices of purchased commodities (price risk)	Mark-to-market gains and losses are recorded as regulatory liabilities and assets, respectively Realized gains and losses are recognized in Fuel expense or Purchased power expense as the contracts settle to match the delivery period of the underlying commodity(2)	(54)		(19)

Notes

(1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the three months ended December 31, 2023 and for the three months ended December 31, 2022.

(2) Of the amount recognized for the three months ended December 31, 2023, $44 million and $10 million were reported in Fuel expense and Purchased power expense, respectively. Of the amount recognized for three months ended December 31, 2022, $15 million and $4 million were reported in Fuel expense and Purchased power expense, respectively.

Fair Values of TVA Derivatives (in millions)
	At December 31, 2023			At September 30, 2023
Derivatives That Receive Hedge Accounting Treatment:
	Balance		Balance Sheet Presentation	Balance		Balance Sheet Presentation
Currency swaps
£250 million Sterling	$	(56)	Accounts payable and accrued liabilities $(5); Other long-term liabilities $(51)	$	(72)	Accounts payable and accrued liabilities $(6); Other long-term liabilities $(66)
£150 million Sterling	(65)		Accounts payable and accrued liabilities $(4); Other long-term liabilities $(61)	(69)		Accounts payable and accrued liabilities $(4); Other long-term liabilities $(65)
Derivatives That Do Not Receive Hedge Accounting Treatment:
	Balance		Balance Sheet Presentation	Balance		Balance Sheet Presentation
Interest rate swaps
$1.0 billion notional	$	(607)	Accounts payable and accrued liabilities $(22); Accrued interest $(6); Other long-term liabilities $(579)	$	(499)	Other current assets $1; Accrued interest $(27); Other long-term liabilities $(473)
$476 million notional	(211)		Accounts payable and accrued liabilities $(8); Other long-term liabilities $(203)	(159)		Other current assets $3; Accrued interest $(8); Other long-term liabilities $(154)
Commodity contract derivatives	29		Other current assets $19; Other long-term assets $12; Accounts payable and accrued liabilities $(1); Other long-term liabilities $(1)	31		Other current assets $21; Other long-term assets $12; Accounts payable and accrued liabilities $(1); Other long-term liabilities $(1)
Commodity derivatives under the FHP	(309)		Accounts payable and accrued liabilities $(212); Other long-term liabilities $(97)	(186)		Accounts payable and accrued liabilities $(135); Other long-term liabilities $(51)

Cash Flow Hedging Strategy for Currency Swaps

To protect against exchange rate risk related to British pound sterling denominated Bond transactions, TVA entered into foreign currency hedges at the time the Bond transactions occurred.  TVA had two currency swaps outstanding at December 31, 2023, with total currency exposure of £400 million and expiration dates in 2032 and 2043.

When the dollar strengthens against the British pound sterling, the exchange gain on the Bond liability and related accrued interest is offset by an equal amount of loss on the swap contract that is reclassified out of AOCI. Conversely, the exchange loss on the Bond liability and related accrued interest is offset by an equal amount of gain on the swap contract that is reclassified out of AOCI. All such exchange gains or losses on the Bond liability and related accrued interest are included in Long-term debt, net and Accrued interest, respectively. The offsetting exchange losses or gains on the swap contracts are recognized in AOCI. If any gain (loss) were to be incurred as a result of the early termination of the foreign currency swap contract, the resulting income (expense) would be amortized over the remaining life of the associated Bond as a component of Interest expense. The values of the currency swap liabilities are included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets.

Derivatives Not Receiving Hedge Accounting Treatment

Interest Rate Derivatives.  Generally TVA uses interest rate swaps to fix variable short-term debt to a fixed rate, and TVA uses regulatory accounting treatment to defer the mark-to-market ("MtM") gains and losses on its interest rate swaps. The net deferred unrealized gains and losses are classified as regulatory liabilities or assets on TVA's Consolidated Balance Sheets and are included in the ratemaking formula when gains or losses are realized. The values of these derivatives are included in Other current assets, Accounts payable and accrued liabilities, Accrued interest, and Other long-term liabilities on the Consolidated Balance Sheets, and realized gains and losses, if any, are included on TVA's Consolidated Statements of Operations. For the three months ended December 31, 2023 and 2022, the changes in fair market value of the interest rate swaps resulted in the increase in unrealized losses of $189 million and reduction in unrealized losses of $14 million, respectively. TVA may hold short-term debt balances lower than the notional amount of the interest rate swaps from time to time due to changes in business conditions and other factors. While actual balances vary, TVA generally plans to maintain average balances of short-term debt equal to or in excess of the combined notional amount of the interest rate swaps.

Commodity Derivatives. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity. TVA may also enter into short-term power purchase agreements ("PPAs") with a term of less than one year that provide an option to financially settle contracted power deliveries. This option creates an embedded derivative in the hosting PPA. TVA marks to market these contracts and defers the unrealized gains (losses) as regulatory liabilities (assets). At December 31, 2023, TVA's natural gas contract derivatives had terms of up to approximately two years.

Commodity Contract Derivatives
	At December 31, 2023				At September 30, 2023
	Number of Contracts	Notional Amount	Fair Value (MtM) (in millions)		Number of Contracts	Notional Amount	Fair Value (MtM) (in millions)
Natural gas contract derivatives	45	366 million mmBtu	$	29	54	318 million mmBtu	$	31

Commodity Derivatives under the FHP. Currently, TVA is hedging exposure to the price of natural gas under the FHP. There is no Value at Risk aggregate transaction limit under the current FHP structure, but the TVA Board reviews and authorizes the use of tolerances and measures annually. TVA's FHP policy prohibits trading financial instruments under the FHP for speculative purposes. At December 31, 2023, TVA's natural gas swap contracts under the FHP had remaining terms of up to approximately four years.

Commodity Derivatives under Financial Hedging Program(1)
	At December 31, 2023					At September 30, 2023
	Number of Contracts	Notional Amount		Fair Value (MtM) (in millions)		Number of Contracts	Notional Amount		Fair Value (MtM) (in millions)
Natural gas
Swap contracts	206	351	million mmBtu	$	(309)	221	388	million mmBtu	$	(186)

Note

(1) Fair value amounts presented are based on the net commodity position with the counterparty. Notional amounts disclosed represent the net value of contractual amounts.

TVA defers all FHP unrealized gains (losses) as regulatory liabilities (assets) and records the realized gains or losses in Fuel expense and Purchased power expense to match the delivery period of the underlying commodity. The fair value of commodity derivatives under the FHP decreased $123 million primarily due to a decrease in forward natural gas prices at December 31, 2023 as compared to September 30, 2023.

Offsetting of Derivative Assets and Liabilities

The amounts of TVA's derivative instruments as reported on the Consolidated Balance Sheets are shown in the table below:

Derivative Assets and Liabilities(1) (in millions)
	At December 31, 2023		At September 30, 2023
Assets
Commodity contract derivatives	$	31	$	33
Interest rate swaps	—		4
Total derivatives subject to master netting or similar arrangement	$	31	$	37
Liabilities
Currency swaps	$	121	$	141
Interest rate swaps(2)	818		662
Commodity contract derivatives	2		2
Commodity derivatives under the FHP(3)	309		186
Total derivatives subject to master netting or similar arrangement	$	1,250	$	991

Notes

(1) Offsetting amounts include counterparty netting of derivative contracts. Except as discussed below, there were no other material offsetting amounts on TVA's Consolidated Balance Sheets at either December 31, 2023, or September 30, 2023.

(2) Letters of credit of $443 million and $509 million were posted as collateral at December 31, 2023, and September 30, 2023, respectively, to partially secure the

liability positions of one of the interest rate swaps in accordance with the collateral requirements for this derivative.

(3) At December 31, 2023, the gross derivative asset and gross derivative liability were $8 million and $317 million, respectively, with offsetting amounts for each totaling $8 million.

Other Derivative Instruments

Investment Fund Derivatives.  Investment funds consist primarily of funds held in the Nuclear Decommissioning Trust ("NDT"), the Asset Retirement Trust ("ART"), the Supplemental Executive Retirement Plan ("SERP"), the TVA Deferred Compensation Plan ("DCP"), and the Restoration Plan ("RP"). See Note 14 — Fair Value Measurements — Investment Funds for a discussion of the trusts, plans, and types of investments. The NDT and ART may invest in derivative instruments which may include swaps, futures, options, forwards, and other instruments. At December 31, 2023, and September 30, 2023, the NDT held investments in forward contracts to purchase debt securities. The fair values of these derivatives were in net asset positions totaling $3 million and $11 million at December 31, 2023, and September 30, 2023, respectively.

Collateral.  TVA's interest rate swaps, currency swaps, and commodity derivatives under the FHP contain contract provisions that require a party to post collateral (in a form such as cash or a letter of credit) when the party's liability balance under the agreement exceeds a certain threshold.  At December 31, 2023, the aggregate fair value of all derivative instruments with credit-risk related contingent features that were in a liability position was $1.3 billion.  TVA's collateral obligations at December 31, 2023, under these arrangements were $537 million, for which TVA had posted $443 million in letters of credit. These letters of credit reduce the available balance under the related credit facilities.  TVA's assessment of the risk of its nonperformance includes a reduction in its exposure under the interest rate swap contracts as a result of this posted collateral.

For all of its derivative instruments with credit-risk related contingent features:

•If TVA remains a majority-owned U.S. government entity but Standard & Poor's Financial Services, LLC or Moody's Investors Service, Inc. ("Moody's") downgrades TVA's credit rating to AA or Aa2, respectively, TVA's collateral obligations would likely increase by $22 million, and

•If TVA ceases to be majority-owned by the U.S. government, TVA's credit rating would likely be downgraded and TVA would be required to post additional collateral.

Counterparty Risk

TVA may be exposed to certain risks when a counterparty has the potential to fail to meet its obligations in accordance with agreed terms. These risks may be related to credit, operational, or nonperformance matters. To mitigate certain counterparty risk, TVA analyzes the counterparty's financial condition prior to entering into an agreement, establishes credit limits, monitors the appropriateness of those limits, as well as any changes in the creditworthiness of the counterparty, on an ongoing basis, and when required, employs credit mitigation measures, such as collateral or prepayment arrangements and master purchase and sale agreements.

Customers.  TVA is exposed to counterparty credit risk associated with trade accounts receivable from delivered power sales to LPCs, and from industries and federal agencies directly served, all located in the Tennessee Valley region. Of the $1.5 billion and $1.6 billion of receivables from power sales outstanding at December 31, 2023, and September 30, 2023, respectively, nearly all of the counterparties were rated investment grade. The obligations of these customers that are not investment grade are secured by collateral. TVA is also exposed to risk from exchange power arrangements with a small number of investor-owned regional utilities related to delivered power. TVA believes its policies and procedures for counterparty performance risk reviews have generally protected TVA against significant exposure related to market and economic conditions. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts, Note 3 — Accounts Receivable, Net, and Note 7 — Other Long-Term Assets.

TVA had revenue from two LPCs that collectively accounted for 16 percent of total operating revenues for both the three months ended December 31, 2023 and the three months ended December 31, 2022.

Suppliers.  TVA assesses potential supplier performance risks, including procurement of fuel, purchased power, parts, and services. If suppliers are unable to perform under TVA's existing contracts or if TVA is unable to obtain similar services or supplies from other vendors, TVA could experience delays, disruptions, additional costs, or other operational outcomes that may impact generation, maintenance, and capital programs. If certain fuel or purchased power suppliers fail to perform under the terms of their contract with TVA, TVA might lose the money that it paid to the supplier under the contract and have to purchase replacement fuel or power on the spot market, perhaps at a significantly higher price than TVA was entitled to pay under the contract. In addition, TVA might not be able to acquire replacement fuel or power in a timely manner and thus might be unable to satisfy its own obligations to deliver power. TVA continues evaluating potential supplier performance risks and supplier impact but cannot determine or predict the duration of such risks/impacts or the extent to which such risks/impacts could affect TVA's business, operations, and financial results or cause potential business disruptions.

TVA continues to experience impacts due to inflation, supply chain material challenges, and labor availability. This has led to project delays and limited availability and/or price increases for supplies and labor. TVA has been able to manage these challenges with limited business disruptions at this time; however, should pressures continue long term, TVA could experience more significant disruptions and pressure to further increase power rates.

Natural Gas and Fuel Oil. TVA purchases a significant amount of its natural gas requirements through contracts with a variety of suppliers and purchases substantially all of its fuel oil requirements on the spot market. TVA delivers to its gas fleet under firm and non-firm transportation contracts on multiple interstate natural gas pipelines. TVA contracts for storage capacity that allows for operational flexibility and increased supply during peak gas demand scenarios or supply disruptions. TVA plans to continue using contracts of various lengths and terms to meet the projected natural gas needs of its natural gas fleet. TVA also maintains on-site, fuel oil backup to operate at the majority of the combustion turbine sites in the event of major supply disruptions. In the event a supplier experiences an incident that limits its ability to fulfill its firm contractual obligations to supply TVA natural gas, TVA will leverage its storage and balancing services and/or replace the volume with a third party to ensure reliability of generation.

Coal. To help ensure a reliable supply of coal, TVA had coal contracts with multiple suppliers at December 31, 2023. The contracted supply of coal is sourced from several geographic regions of the U.S. and is delivered via barge and rail. As a result of emerging technologies, environmental regulations, industry trends, and natural gas market volatility over the past few years, coal suppliers are facing increased financial pressure, which has led to relatively poor credit ratings and bankruptcies, restructuring, mine closures, or other scenarios. A long-term continued decline in demand for coal could result in more consolidations, additional bankruptcies, restructuring, mine closures, or other scenarios.

Nuclear Fuel. Nuclear fuel is obtained predominantly through long-term uranium concentrate supply contracts, contracted conversion services, contracted enrichment services, or a combination thereof, and contracted fuel fabrication services. The supply markets for uranium concentrates and certain nuclear fuel services are subject to price fluctuations and availability restrictions. Supply market conditions may make procurement contracts subject to credit risk related to the potential nonperformance of counterparties. In the event of nonperformance by these or other suppliers, TVA believes that replacement uranium concentrate and nuclear fuel services can be obtained, although at prices that may be unfavorable when compared to the prices under the current supply agreements.

As a result of Russia’s invasion of Ukraine, new contracts for Russian origin nuclear fuel have been limited by Executive Order ("EO") 14066, and further restrictions on the purchase or use of Russian origin fuel may be forthcoming. TVA should have no direct impact from existing or future restrictions since TVA has no Russian origin nuclear fuel in inventory for use in its reactors and it is not contracted to purchase any Russian origin nuclear fuel. TVA could be impacted by higher market prices as a result of general market impacts associated with supply restrictions; however, at this time TVA's nuclear fuel is obtained predominantly through long-term contracts.

Purchased Power. TVA acquires power from a variety of power producers through long-term and short-term PPAs as well as through spot market purchases. Because of the reliability risk of purchased power, TVA requires that the PPAs contain certain counterparty performance assurance requirements to help insure counterparty performance during the term of the agreements.

Other Suppliers. Mounting solar supply chain constraints, commodity price increases, and the recent trade policy investigation into solar panel imports have created challenges for the U.S. solar industry. TVA's Self-Directed Solar project and TVA's existing solar PPA portfolio are not immune from these challenges. Similar to the experience of the rest of the industry, the majority of TVA's contracted PPAs from previous requests for proposals ("RFPs") that are not yet online have been impacted by project delays and price increases, and TVA terminated one PPA because of counterparty default.

Derivative Counterparties.  TVA has entered into physical and financial contracts that are classified as derivatives for hedging purposes, and TVA's NDT, ART, and qualified defined benefit plan ("pension plan") have entered into derivative contracts for investment purposes. If a counterparty to one of the physical or financial derivative transactions defaults, TVA might incur costs in connection with entering into a replacement transaction. If a counterparty to the derivative contracts into which the NDT, the ART, or the pension plan have entered for investment purposes defaults, the value of the investment could decline significantly or perhaps become worthless. TVA has concentrations of credit risk from the banking, coal, and gas industries because multiple companies in these industries serve as counterparties to TVA in various derivative transactions. At December 31, 2023, all of TVA's commodity derivatives under the FHP, currency swaps, and interest rate swaps were with counterparties whose Moody's credit ratings were A2 or higher. TVA classifies forward natural gas contracts as derivatives. At December 31, 2023, the forward natural gas contracts were with counterparties whose ratings ranged from B1 to A1.

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Fair Value Measurements

3 Months Ended

Dec. 31, 2023

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

Fair value is determined based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the asset or liability's principal market, or in the absence of a principal market, the most advantageous market for the asset or liability in an orderly transaction between market participants. TVA uses market or observable inputs as the preferred source of values, followed by assumptions based on hypothetical transactions in the absence of market inputs.

Valuation Techniques

The measurement of fair value results in classification into a hierarchy by the inputs used to determine the fair value as follows:

Level 1	—	Unadjusted quoted prices in active markets accessible by the reporting entity for identical assets or liabilities.  Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing.
Level 2	—	Pricing inputs other than quoted market prices included in Level 1 that are based on observable market data and that are directly or indirectly observable for substantially the full term of the asset or liability.  These include quoted market prices for similar assets or liabilities, quoted market prices for identical or similar assets in markets that are not active, adjusted quoted market prices, inputs from observable data such as interest rate and yield curves, volatilities and default rates observable at commonly quoted intervals, and inputs derived from observable market data by correlation or other means.
Level 3	—	Pricing inputs that are unobservable, or less observable, from objective sources.  Unobservable inputs are only to be used to the extent observable inputs are not available.  These inputs maintain the concept of an exit price from the perspective of a market participant and should reflect assumptions of other market participants.  An entity should consider all market participant assumptions that are available without unreasonable cost and effort.  These are given the lowest priority and are generally used in internally developed methodologies to generate management's best estimate of the fair value when no observable market data is available.

A financial instrument's level within the fair value hierarchy (where Level 1 is the highest and Level 3 is the lowest) is based on the lowest level of input significant to the fair value measurement.

The following sections describe the valuation methodologies TVA uses to measure different financial instruments at fair value. Except for gains and losses on SERP and DCP assets, all changes in fair value of these assets and liabilities have been recorded as changes in regulatory assets, regulatory liabilities, or AOCI on TVA's Consolidated Balance Sheets and Consolidated Statements of Comprehensive Income (Loss). Except for gains and losses on SERP and DCP assets, there has been no impact to the Consolidated Statements of Operations or the Consolidated Statements of Cash Flows related to these fair value measurements.

Investment Funds

At December 31, 2023, Investment funds were comprised of $4.5 billion of equity securities and debt securities classified as trading measured at fair value. Equity and trading debt securities are held in the NDT, ART, SERP, DCP, and RP. The NDT holds funds for the ultimate decommissioning of TVA's nuclear power plants. The ART holds funds primarily for the costs related to the future closure and retirement of TVA's other long-lived assets. The balances in the NDT and ART were $3.0 billion and $1.3 billion, respectively, at December 31, 2023.

TVA established a SERP to provide benefits to selected employees of TVA which are comparable to those provided by competing organizations. The DCP is designed to provide participants with the ability to defer compensation to future periods. The RP is a non-qualified excess 401(k) plan designed to allow certain eligible employees whose contributions to the 401(k) plan are limited by Internal Revenue Service ("IRS") rules to save additional amounts for retirement and receive non-elective and matching employer contributions. The NDT, ART, SERP, DCP, and RP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity and debt market performance.

The NDT, ART, SERP, DCP, and RP are composed of multiple types of investments and are managed by external institutional investment managers. Most U.S. and international equities, U.S. Treasury inflation-protected securities, real estate investment trust securities, and cash securities and certain derivative instruments are measured based on quoted exchange prices in active markets and are classified as Level 1 valuations. Fixed-income investments, high-yield fixed-income investments, currencies, and most derivative instruments are non-exchange traded and are classified as Level 2 valuations. These measurements are based on market and income approaches with observable market inputs.

Private equity limited partnerships, private real asset investments, and private credit investments may include holdings of investments in private real estate, venture capital, buyout, mezzanine or subordinated debt, restructuring or distressed debt,

and special situations through funds managed by third-party investment managers. These investments generally involve a three-to-four-year period where the investor contributes capital, followed by a period of distribution, typically over several years. The investment period is generally, at a minimum, 10 years or longer. The NDT had unfunded commitments related to private equity limited partnerships of $296 million, private real assets of $110 million, and private credit of $88 million at December 31, 2023. The ART had unfunded commitments related to limited partnerships in private equity of $122 million, private real assets of $54 million, and private credit of $47 million at December 31, 2023. These investments have no redemption or limited redemption options and may also impose restrictions on the NDT's and ART's ability to liquidate their investments. There are no readily available quoted exchange prices for these investments. The fair value of these investments is based on information provided by the investment managers. These investments are valued on a quarterly basis. TVA's private equity limited partnerships, private real asset investments, and private credit investments are valued at net asset values ("NAV") as a practical expedient for fair value. TVA classifies its interest in these types of investments as investments measured at NAV in the fair value hierarchy.

Commingled funds represent investment funds comprising multiple individual financial instruments. The commingled funds held by the NDT, ART, SERP, DCP, and RP consist of either a single class of securities, such as equity, debt, or foreign currency securities, or multiple classes of securities. All underlying positions in these commingled funds are either exchange traded or measured using observable inputs for similar instruments. The fair value of commingled funds is based on NAV per fund share (the unit of account), derived from the prices of the underlying securities in the funds. These commingled funds can be redeemed at the measurement date NAV and are classified as Commingled funds measured at NAV in the fair value hierarchy.

Realized and unrealized gains and losses on equity and trading debt securities are recognized in current earnings and are based on average cost. The gains and losses of the NDT and ART are subsequently reclassified to a regulatory asset or liability account in accordance with TVA's regulatory accounting policy. See Note 1 — Summary of Significant Accounting Policies of the Notes to Consolidated Financial Statements in the Annual Report and Note 8 — Regulatory Assets and Liabilities. TVA recorded unrealized gains and losses related to its equity and trading debt securities held during each period as follows:

Unrealized Investment Gains (Losses)(1) (in millions)
		Three Months Ended December 31
Fund	Financial Statement Presentation	2023		2022
NDT	Regulatory assets(2)	$	197	$	136
ART	Regulatory assets(3)	89		69
SERP	Other income, net	7		3
DCP	Other income, net	1		—

Notes

(1) Employee contributions to the RP began in the second quarter of 2023. As of December 31, 2023, the unrealized gains for the RP were less than $1 million, and therefore were not represented in the table above.

(2) Includes $61 million and $20 million of unrealized gains related to NDT equity securities (excluding commingled funds) for the three months ended December 31, 2023 and 2022, respectively.

(3) Includes $18 million and $10 million of unrealized gains related to ART equity securities (excluding commingled funds) for the three months ended December 31, 2023 and 2022, respectively.

Currency and Interest Rate Swap Derivatives

See Note 13 — Risk Management Activities and Derivative Transactions — Cash Flow Hedging Strategy for Currency Swaps and Derivatives Not Receiving Hedge Accounting Treatment for a discussion of the nature, purpose, and contingent features of TVA's currency swaps and interest rate swaps. These swaps are classified as Level 2 valuations and are valued based on income approaches using observable market inputs for similar instruments.

Commodity Contract Derivatives and Commodity Derivatives under the FHP

Commodity Contract Derivatives. Most of these derivative contracts are valued based on market approaches, which utilize short-term and mid-term market-quoted prices from an external industry brokerage service. These contracts are classified as Level 2 valuations.

Commodity Derivatives under the FHP. Swap contracts are valued using a pricing model based on New York Mercantile Exchange inputs and are subject to nonperformance risk outside of the exit price. These contracts are classified as Level 2 valuations.

See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP.

Nonperformance Risk

The assessment of nonperformance risk, which includes credit risk, considers changes in current market conditions, readily available information on nonperformance risk, letters of credit, collateral, other arrangements available, and the nature of master netting arrangements. TVA is a counterparty to currency swaps, interest rate swaps, commodity contracts, and other derivatives which subject TVA to nonperformance risk. Nonperformance risk on the majority of investments and certain exchange-traded instruments held by TVA is incorporated into the exit price that is derived from quoted market data that is used to mark the investment to market.

Nonperformance risk for most of TVA's derivative instruments is an adjustment to the asset/liability fair value. TVA adjusts for nonperformance risk, both of TVA (for liabilities) and the counterparty (for assets), by applying credit valuation adjustments ("CVAs"). TVA determines an appropriate CVA for each applicable financial instrument based on the term of the instrument and TVA's or the counterparty's credit rating as obtained from Moody's. For companies that do not have an observable credit rating, TVA uses internal analysis to assign a comparable rating to the counterparty. TVA discounts each financial instrument using the historical default rate (as reported by Moody's for CY 1983 to CY 2022) for companies with a similar credit rating over a time period consistent with the remaining term of the contract. The application of CVAs resulted in a $1 million decrease in the fair value of assets and a $1 million decrease in the fair value of liabilities at December 31, 2023.

Fair Value Measurements

The following tables set forth by level, within the fair value hierarchy, TVA's financial assets and liabilities that were measured at fair value on a recurring basis at December 31, 2023, and September 30, 2023. Financial assets and liabilities have been classified in their entirety based on the lowest level of input that is significant to the fair value measurement. TVA's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the determination of the fair value of the assets and liabilities and their classification in the fair value hierarchy levels.

Fair Value Measurements At December 31, 2023 (in millions)
	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Assets
Investments
Equity securities	$	684	$	—	$	—	$	684
Government debt securities(1)	453		69		—		522
Corporate debt securities(2)	—		321		—		321
Mortgage and asset-backed securities	—		37		—		37
Institutional mutual funds	309		—		—		309
Forward debt securities contracts	—		3		—		3
Cash equivalents and other short-term investments	—		163		—		163
Private equity funds measured at net asset value(3)	—		—		—		657
Private real asset funds measured at net asset value(3)	—		—		—		408
Private credit funds measured at net asset value(3)	—		—		—		184
Commingled funds measured at net asset value(3)	—		—		—		1,184
Total investments	1,446		593		—		4,472
Commodity contract derivatives	—		31		—		31
Total	$	1,446	$	624	$	—	$	4,503
	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Liabilities
Currency swaps(4)	$	—	$	121	$	—	$	121
Interest rate swaps	—		818		—		818
Commodity contract derivatives	—		2		—		2
Commodity derivatives under the FHP	—		309		—		309
Total	$	—	$	1,250	$	—	$	1,250

Notes

(1) Includes securities of government-sponsored entities, including $453 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.

(2) Includes both U.S. and foreign debt.

(3) Certain investments that are measured at fair value using the NAV or its equivalent (alternative investments) have not been categorized in the fair value hierarchy. The inputs to these fair value measurements include underlying NAVs, discounted cash flow valuations, comparable market valuations, and adjustments for currency, credit, liquidity, and other risks. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented on the Consolidated Balance Sheets.

(4) TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

Fair Value Measurements At September 30, 2023 (in millions)
	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Assets
Investments
Equity securities	$	608	$	—	$	—	$	608
Government debt securities(1)(2)	391		60		—		451
Corporate debt securities(3)	—		300		—		300
Mortgage and asset-backed securities	—		36		—		36
Institutional mutual funds	288		—		—		288
Forward debt securities contracts	—		11		—		11
Cash equivalents and other short-term investments(2)	—		145		—		145
Private equity funds measured at net asset value(4)	—		—		—		583
Private real asset funds measured at net asset value(4)	—		—		—		387
Private credit funds measured at net asset value(4)	—		—		—		158
Commingled funds measured at net asset value(2)(4)	—		—		—		1,156
Total investments	1,287		552		—		4,123
Interest rate swaps	—		4		—		4
Commodity contract derivatives	—		33		—		33
Total	$	1,287	$	589	$	—	$	4,160
	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Liabilities
Currency swaps(5)	$	—	$	141	$	—	$	141
Interest rate swaps	—		662		—		662
Commodity contract derivatives	—		2		—		2
Commodity derivatives under the FHP	—		186		—		186
Total	$	—	$	991	$	—	$	991

Notes

(1) Includes securities of government-sponsored entities, including $391 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.

(2) At September 30, 2023, $104 million previously classified as Level 1 Cash equivalents and other short-term investments have been reclassified to Level 1 Government debt securities to conform with current year presentation. At September 30, 2023, $21 million previously classified as Level 2 Cash equivalents and other short-term investments have been reclassified to Commingled funds measured at net asset value to conform with current year presentation.

(3) Includes both U.S. and foreign debt.

(4) Certain investments that are measured at fair value using the NAV or its equivalent (alternative investments) have not been categorized in the fair value hierarchy. The inputs to these fair value measurements include underlying NAVs, discounted cash flow valuations, comparable market valuations, and adjustments for currency, credit, liquidity, and other risks. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented on the Consolidated Balance Sheets.

(5)  TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

Other Financial Instruments Not Recorded at Fair Value

TVA uses the methods and assumptions described below to estimate the fair value of each significant class of financial instruments. The fair value of the financial instruments held at December 31, 2023, and September 30, 2023, may not be representative of the actual gains or losses that will be recorded when these instruments mature or are called or presented for early redemption. The estimated values of TVA's financial instruments not recorded at fair value at December 31, 2023, and September 30, 2023, were as follows:

Estimated Values of Financial Instruments Not Recorded at Fair Value (in millions)
		At December 31, 2023				At September 30, 2023
	Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value
EnergyRight® receivables, net (including current portion)	Level 2	$	59	$	55	$	59	$	55
Loans and other long-term receivables, net (including current portion)	Level 2	105		97		104		96
EnergyRight® financing obligations (including current portion)	Level 2	69		81		69		81
Unfunded loan commitments	Level 2	—		—		—		1
Membership interests of VIEs subject to mandatory redemption (including current portion)	Level 2	18		20		18		19
Long-term outstanding power bonds, net (including current maturities)	Level 2	18,889		19,079		18,866		17,963
Long-term debt of VIEs, net (including current maturities)	Level 2	968		987		968		927

The carrying value of Cash and cash equivalents, Restricted cash and cash equivalents, Accounts receivable, net, and Short-term debt, net approximate their fair values.

The fair value for loans and other long-term receivables is estimated by determining the present value of future cash flows using a discount rate equal to lending rates for similar loans made to borrowers with similar credit ratings and for similar remaining maturities, where applicable. The fair value of long-term debt and membership interests of VIEs subject to mandatory redemption is estimated by determining the present value of future cash flows using current market rates for similar obligations, giving effect to credit ratings and remaining maturities.

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Other Income (Expense), Net

3 Months Ended

Dec. 31, 2023

Other Income and Expenses [Abstract]

Other Income (Expense), Net

Other Income, Net

Income and expenses not related to TVA's operating activities are summarized in the following table:

Other Income, Net (in millions)
	Three Months Ended December 31
	2023		2022
Interest income	$	10	$	7
External services	4		3
Gains on investments	9		6
Total other income, net	$	23	$	16

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Benefit Plans

3 Months Ended

Dec. 31, 2023

Retirement Benefits [Abstract]

Benefit Plans

Benefit Plans

TVA sponsors a pension plan that covers most of its full-time employees hired before July 1, 2014, a qualified defined contribution plan ("401(k) plan") that covers most of its full-time employees, two unfunded post-retirement health care plans that provide for non-vested contributions toward the cost of eligible retirees' medical coverage, other post-employment benefits, such as workers' compensation, the SERP, and the RP. The pension plan and the 401(k) plan are administered by a separate legal entity, the TVA Retirement System ("TVARS"), which is governed by its own board of directors.

The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the three months ended December 31, 2023 and 2022, were as follows:

Components of TVA's Benefit Plans(1) (in millions)
	For the Three Months Ended December 31
	Pension Benefits				Other Post-Retirement Benefits
	2023		2022		2023		2022
Service cost	$	7	$	9	$	3	$	3
Interest cost	144		142		5		5
Expected return on plan assets	(124)		(123)		—		—
Amortization of prior service credit	(22)		(22)		(4)		(4)
Recognized net actuarial loss (gain)	25		34		(1)		—
Total net periodic benefit cost as actuarially determined	30		40		3		4
Amount expensed due to actions of regulator	—		19		—		—
Total net periodic benefit cost	$	30	$	59	$	3	$	4

Note

(1) The components of net benefit cost other than the service cost component are included in Other net periodic benefit cost on the Consolidated Statements of Operations.

TVA's minimum required pension plan contribution for 2024 is $300 million. TVA contributes $25 million per month to TVARS and as of December 31, 2023, had contributed $75 million. The remaining $225 million will be contributed by September 30, 2024. For the three months ended December 31, 2023, TVA also contributed $35 million to the 401(k) plan and $8 million (net of $1 million in rebates) to the other post-retirement plans. TVA expects to contribute $6 million to the SERP in 2024.

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Contingencies and Legal Proceedings

3 Months Ended

Dec. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

Contingencies and Legal Proceedings

20.  Contingencies and Legal Proceedings

Contingencies

Nuclear Insurance.  Section 170 of the Atomic Energy Act, commonly known as the Price-Anderson Act, provides a layered framework of financial protection to compensate for liability claims of members of the public for personal injury and property damages arising from a nuclear incident in the U.S. This financial protection consists of two layers of coverage. The primary level is private insurance underwritten by American Nuclear Insurers and provides public liability insurance coverage of $450 million for each nuclear power plant licensed to operate. If this amount is not sufficient to cover claims arising from a nuclear incident, the second level, Secondary Financial Protection, applies. Within the Secondary Financial Protection level, the licensee of each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident of fault, up to a maximum of approximately $166 million per reactor per incident. With TVA's seven reactors, the maximum total contingent obligation per incident is $1.2 billion. This retrospective premium is payable at a maximum rate currently set at approximately $25 million per year per nuclear incident per reactor. Currently, 95 reactors are participating in the Secondary Financial Protection program.

In the event that a nuclear incident results in public liability claims, the primary level provided by American Nuclear Insurers combined with the Secondary Financial Protection should provide up to $16.2 billion in coverage.

Federal law requires that each Nuclear Regulatory Commission ("NRC") power reactor licensee obtain property insurance from private sources to cover the cost of stabilizing and decontaminating a reactor and its station site after an accident. TVA carries property, decommissioning liability, and decontamination liability insurance from Nuclear Electric Insurance Limited ("NEIL") and European Mutual Association for Nuclear Insurance. The limits available for a loss are up to $2.1 billion for two of TVA's nuclear sites and up to $2.8 billion for the remaining site. Some of this insurance may require the payment of retrospective premiums up to a maximum of approximately $114 million.

TVA purchases accidental outage (business interruption) insurance for TVA's nuclear sites from NEIL.  In the event that an accident covered by this policy takes a nuclear unit offline or keeps a nuclear unit offline, NEIL will pay TVA, after a waiting period, an indemnity (a set dollar amount per week) with a maximum indemnity of $490 million per unit.  This insurance policy may require the payment of retrospective premiums up to a maximum of approximately $44 million, but only to the extent the retrospective premium is deemed necessary by the NEIL Board of Directors to pay losses unable to be covered by NEIL's surplus.

Decommissioning Costs.  TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets related primarily to nuclear generating plants, coal-fired generating plants, hydroelectric generating plants/dams, transmission structures, and other property-related assets. See Note 11 — Asset Retirement Obligations.

Nuclear Decommissioning.  Provision for decommissioning costs of nuclear generating units is based on options prescribed by the NRC procedures to dismantle and decontaminate the facilities to meet the NRC criteria for license termination. At December 31, 2023, $3.8 billion, representing the discounted value of future estimated nuclear decommissioning costs, was included in nuclear AROs.  The actual decommissioning costs may vary from the derived estimates because of, among other things, changes in current assumptions, such as the assumed dates of decommissioning, changes in regulatory requirements, changes in technology, and changes in the cost of labor, materials, and equipment.  Utilities that own and operate nuclear plants are required to use different procedures in calculating nuclear decommissioning costs under GAAP than those that are used in calculating nuclear decommissioning costs when reporting to the NRC.  The two sets of procedures produce different estimates for the costs of decommissioning primarily because of differences in the underlying assumptions. TVA bases its nuclear decommissioning estimates on site-specific cost studies. The most recent study was approved and implemented in September 2022. Site-specific cost studies are updated for each of TVA's nuclear units at least every five years.

TVA maintains an NDT to provide funding for the ultimate decommissioning of its nuclear power plants.  See Note 14 — Fair Value Measurements — Investment Funds. TVA monitors the value of its NDT and believes that, over the long term and before cessation of nuclear plant operations and commencement of decommissioning activities, adequate funds from investments and additional contributions, if necessary, will be available to support decommissioning.  TVA's operating nuclear power units are licensed through various dates between 2033 - 2055, depending on the unit.  It may be possible to extend the operating life of some of the units with approval from the NRC. See Note 8 — Regulatory Assets and Liabilities and Note 11 — Asset Retirement Obligations.

Non-Nuclear Decommissioning.  At December 31, 2023, $3.7 billion, representing the discounted value of future estimated non-nuclear decommissioning costs, was included in non-nuclear AROs.  This decommissioning cost estimate involves estimating the amount and timing of future expenditures and making judgments concerning whether or not such costs are considered a legal obligation.  Estimating the amount and timing of future expenditures includes, among other things, making projections of the timing and duration of the asset retirement process and how costs will escalate with inflation.  The actual decommissioning costs may vary from the derived estimates because of changes in current assumptions, such as the assumed dates of decommissioning, changes in regulatory requirements, changes in technology, and changes in the cost of labor, materials, and equipment. TVA updates its underlying assumptions for non-nuclear decommissioning AROs at least every five

years. However, material changes in underlying assumptions that impact the amount and timing of undiscounted cash flows are continuously monitored and incorporated into ARO balances in the period identified.

TVA maintains an ART to help fund the ultimate decommissioning of its non-nuclear power assets.  See Note 14 — Fair Value Measurements — Investment Funds. Estimates involved in determining if additional funding will be made to the ART include inflation rate, rate of return projections on the fund investments, and the planned use of other sources to fund decommissioning costs. See Note 8 — Regulatory Assets and Liabilities and Note 11 — Asset Retirement Obligations.

Environmental Matters. TVA's generation activities, like those across the utility industry and in other industrial sectors, are subject to federal, state, and local environmental laws and regulations.  Major areas of regulation affecting TVA's activities include air quality control, greenhouse gas ("GHG") emissions, water quality control, and management and disposal of solid and hazardous wastes.  Regulations in these major areas continue to become more stringent and have, and will continue to have, a particular emphasis on climate change, renewable generation, and energy efficiency.

TVA has incurred, and expects to continue to incur, substantial capital and operating and maintenance costs to comply with evolving environmental requirements primarily associated with, but not limited to, the operation of TVA's coal-fired and natural gas-fired generating units in general and emissions of pollutants from those units.  Environmental requirements placed on the operation of coal-fired and other generating units using fossil fuels such as oil and natural gas will likely continue to become more restrictive over time. Failure to comply with environmental and safety requirements can result in enforcement actions and litigation, which can lead to the imposition of significant civil liability, including fines and penalties, criminal sanctions, and/or temporary or permanent closure of non-compliant facilities. Historical non-compliance can also lead to difficulty in renewing existing permits, as well as difficulty in obtaining permits to bring new generation facilities online. Other obstacles to renewal or permitting of new facilities include a proliferation of non-government organizations seeking to use litigation tools to delay or stop altogether permitting of new fossil fuel facilities in favor of renewable energy projects.

TVA estimates that compliance with existing Clean Air Act requirements (excluding GHG requirements and new or proposed regulations) could lead to costs of $228 million from 2024 to 2028, which include existing controls capital projects and air operations and maintenance projects. TVA also estimates additional expenditures of $1.6 billion from 2024 to 2028 relating to TVA's coal combustion residuals ("CCR") Program, as well as expenditures of $197 million from 2024 to 2028 relating to compliance with Clean Water Act requirements. Future costs could differ from these estimates if, among other things, new environmental laws or regulations become applicable to TVA or the facilities it operates, or if existing environmental laws or regulations are revised or reinterpreted.  There could also be costs that cannot reasonably be predicted at this time, due to uncertainty of actions, that could increase these estimates, and these estimates do not include expenditures expected to be incurred after 2028.

Compliance with the Environmental Protection Agency's CCR rule required implementation of a groundwater monitoring program, additional engineering, and ongoing analysis. As further analyses are performed, including evaluation of monitoring results, there is the potential for additional costs for investigation and/or remediation. These costs cannot reasonably be predicted until a final remedy is selected where required.

Liability for releases, natural resource damages, and required cleanup of hazardous substances is primarily regulated by the federal Comprehensive Environmental Response, Compensation, and Liability Act ("CERCLA"), the Resource Conservation and Recovery Act ("RCRA"), and other federal and parallel state statutes.  In a manner similar to many other governmental entities, industries, and power systems, TVA has generated or used hazardous substances over the years. TVA operations at some facilities have resulted in releases of contaminants that TVA has addressed or is addressing consistent with state and federal requirements.  At both December 31, 2023 and September 30, 2023, TVA's estimated liability for required cleanup and similar environmental work for those sites for which sufficient information is available to develop a cost estimate was approximately $16 million on a non-discounted basis and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. Additionally, the potential inclusion of new hazardous substances under CERCLA and RCRA jurisdiction could significantly affect TVA's future liability for remediating historical releases.

In August 2015, Tennessee Department of Environment and Conservation ("TDEC") issued an order that includes an iterative process through which TVA and TDEC will identify and evaluate any CCR contamination risks and, if necessary, respond to such risks. As part of this process, TVA has submitted Environmental Assessment Reports ("EARs") to TDEC, and after the EARs are approved, TVA will submit Corrective Action/Risk Assessment Plans that will identify the unacceptable risks and TVA's proposed remediation. At December 31, 2023, TVA's estimated liability for costs associated with these environmental remediation activities for sites for which sufficient information is available to develop a cost estimate was approximately $26 million and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets.

Potential Liability Associated with Workers' Exposure to CCR Materials. In response to the 2008 ash spill at Kingston Fossil Plant, TVA hired Jacobs Engineering Group, Inc. ("Jacobs") to oversee aspects of the cleanup. After the cleanup was completed, Jacobs was sued in the U.S. District Court for the Eastern District of Tennessee ("Eastern District") by employees of a contractor involved in the cleanup and family members of some of the employees. The plaintiffs alleged that Jacobs failed to take or provide proper health precautions and misled workers about the health risks associated with exposure to coal fly ash,

which is a CCR material. The plaintiffs also alleged that exposure to the fly ash caused significant illnesses, including in some cases death. Other contractor employees and family members also filed similar lawsuits against Jacobs in the Eastern District. In the third quarter of 2023, Jacobs announced that it reached a global settlement that resolved all of these lawsuits. While TVA was not a party to any of these lawsuits, TVA may potentially have an indemnity obligation to reimburse Jacobs in some circumstances. TVA does not expect any potential liability to have a material adverse impact on its results of operations or financial condition.

Legal Proceedings

There have been no material changes to the legal proceedings described in Note 22 — Commitments and Contingencies — Legal Proceedings of the Annual Report.

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Revenue (Notes)

3 Months Ended

Dec. 31, 2023

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer [Text Block]

Revenue

Revenue from Sales of Electricity

TVA's revenue from contracts with customers is primarily derived from the generation and sale of electricity to its customers and is included in Revenue from sales of electricity on the Consolidated Statements of Operations. Electricity is sold primarily to LPCs for distribution to their end-use customers. In addition, TVA sells electricity to directly served industrial companies, federal agencies, and others.

LPC sales

Approximately 91 percent of TVA's Revenue from sales of electricity for both the three months ended December 31, 2023 and 2022, was from LPCs, which then distribute the power to their customers using their own distribution systems. Power is delivered to each LPC at delivery points within the LPC's service territory. TVA recognizes revenue when the customer takes possession of the power at the delivery point. For power sales, the performance obligation to deliver power is satisfied in a series over time because the sales of electricity over the term of the customer contract are a series of distinct goods that are substantially the same and have the same pattern of transfer to the customer. TVA has no continuing performance obligations subsequent to delivery. Using the output method for revenue recognition provides a faithful depiction of the transfer of electricity as customers obtain control of the power and benefit from its use at delivery. Additionally, TVA has an enforceable right to consideration for energy delivered at any discrete point in time and will recognize revenue at an amount that reflects the consideration to which TVA is entitled for the energy delivered. The amount of revenue is based on contractual prices approved by the TVA Board. Customers are invoiced monthly for power delivered as measured by meters located at the delivery points. The net transaction price is offset by certain credits available to customers that are known at the time of billing. Credits are designed to achieve objectives of the TVA Act and include items such as hydro preference credits for residential customers of LPCs, economic development credits to promote growth in the Tennessee Valley, wholesale bill credits to maintain long-term partnerships with LPCs, and demand response credits allowing TVA to reduce industrial customer usage in periods of peak demand to balance system demand. Payments are typically due within approximately one month of invoice issuance.

Directly served customers

Directly served customers, including industrial customers, federal agencies, and other customers, take power for their own consumption. Similar to LPCs, power is delivered to a delivery point, at which time the customer takes possession and TVA recognizes revenue. For all power sales, the performance obligation to deliver power is satisfied in a series over time since the sales of electricity over the term of the customer contract are a series of distinct goods that are substantially the same and have the same pattern of transfer to the customer. TVA has no continuing performance obligations subsequent to delivery. Using the output method for revenue recognition provides a faithful depiction of the transfer of electricity as customers obtain control of the power and benefit from its use at delivery. Additionally, TVA has an enforceable right to consideration for energy delivered at any discrete point in time and will recognize revenue at an amount that reflects the consideration to which TVA is entitled for the energy delivered. The amount of revenue is based on contractual prices approved by the TVA Board. Customers are invoiced monthly for power delivered as measured by meters located at the delivery points. The net transaction price is offset by certain credits available to customers that are known at the time of billing. Examples of credits include items such as economic development credits to promote growth in the Tennessee Valley and demand response credits allowing TVA to reduce industrial customer usage in periods of peak demand to balance system demand. Payments are typically due within approximately one month of invoice issuance.

Other Revenue

Other revenue consists primarily of wheeling and network transmission charges, sales of excess steam that is a by-product of power production, delivery point charges for interconnection points between TVA and the customer, Renewable Energy Certificate sales, and certain other ancillary goods or services.

Disaggregated Revenues

During the three months ended December 31, 2023, revenues generated from TVA's electricity sales were $2.7 billion, and accounted for virtually all of TVA's revenues. TVA's operating revenues by state for the three months ended December 31, 2023 and 2022, are detailed in the table below:

Operating Revenues By State (in millions)
	Three Months Ended December 31
	2023		2022
Alabama	$	408	$	428
Georgia	69		76
Kentucky	177		198
Mississippi	255		278
North Carolina	23		25
Tennessee	1,789		1,941
Virginia	11		13
Subtotal	2,732		2,959
Off-system sales	2		4
Revenue capitalized during pre-commercial plant operations(1)	(3)		—
Revenue from sales of electricity	2,731		2,963
Other revenue	34		52
Total operating revenues	$	2,765	$	3,015

Note

(1) Represents revenue capitalized during pre-commercial operations at Paradise Combustion Turbine Units 5-7.

TVA's operating revenues by customer type for the three months ended December 31, 2023 and 2022, are detailed in the table below:

Operating Revenues by Customer Type (in millions)
	Three Months Ended December 31
	2023		2022
Revenue from sales of electricity
Local power companies	$	2,487	$	2,706
Industries directly served	217		225
Federal agencies and other	30		32
Revenue capitalized during pre-commercial plant operations(1)	(3)		—
Revenue from sales of electricity	2,731		2,963
Other revenue	34		52
Total operating revenues	$	2,765	$	3,015

Note

(1) Represents revenue capitalized during pre-commercial operations at Paradise Combustion Turbine Units 5-7.

TVA and LPCs continue to work together to meet the changing needs of consumers around the Tennessee Valley. In 2019, the TVA Board approved a partnership agreement option that better aligns the length of LPC power contracts with TVA's long-term commitments. Under the partnership arrangement, the LPC power contracts automatically renew each year and have a 20-year termination notice. The partnership arrangements can be terminated under certain circumstances, including TVA's failure to limit rate increases as provided for in the agreements going forward. Participating LPCs receive benefits including a 3.1 percent wholesale bill credit in exchange for their long-term commitment, which enables TVA to recover its long-term financial commitments over a commensurate period. The total wholesale bill credits to LPCs participating in the Partnership Agreement were $47 million and $48 million for the three months ended December 31, 2023 and 2022, respectively. In 2020, TVA provided participating LPCs a flexibility option, named Generation Flexibility, that allows them to locally generate or purchase up to approximately five percent of their average total hourly energy sales over a certain time period in order to meet their individual customers' needs. Revised flexibility agreements were made available to LPCs in 2023 which permit projects to be located anywhere in TVA's service area, either connected to the LPC distribution system or TVA's transmission system, and make it easier for LPCs to partner in projects. As of December 31, 2023, 147 LPCs had signed the Partnership Agreement with TVA,

and 92 LPCs had signed a Power Supply Flexibility Agreement.

The number of LPCs by contract arrangement, the revenues derived from such arrangements for the three months ended December 31, 2023, and the percentage those revenues comprised of TVA's total operating revenues for the same period, are summarized in the table below:

TVA Local Power Company Contracts At or for the Three Months Ended December 31, 2023
Contract Arrangements(1)	Number of LPCs	Revenue from Sales of Electricity to LPCs (in millions)		Percentage of Total Operating Revenues
20-year termination notice	147	$	2,156	78.0	%
5-year termination notice	6	331		12.0	%
Total	153	$	2,487	90.0	%

Note

(1) Ordinarily, the LPCs and TVA have the same termination notice period; however, in a contract with one of the LPCs with a five-year termination notice, TVA has a 10-year termination notice (which becomes a five-year termination notice if TVA loses its discretionary wholesale rate-setting authority). Certain LPCs have five-year termination notices or a shorter period if any act of Congress, court decision, or regulatory change requires or permits that election.

TVA's two largest LPCs — Memphis Light, Gas and Water Division ("MLGW") and Nashville Electric Service ("NES") — have contracts with a five-year and a 20-year termination notice period, respectively. Sales to MLGW and NES each accounted for eight percent of TVA's total operating revenues for both the three months ended December 31, 2023 and the three months ended December 31, 2022.

Contract Balances

Contract assets represent an entity's right to consideration in exchange for goods and services that the entity has transferred to customers. TVA did not have any material contract assets at December 31, 2023.

Contract liabilities represent an entity's obligations to transfer goods or services to customers for which the entity has received consideration (or an amount of consideration is due) from the customers. These contract liabilities are primarily related to upfront consideration received prior to the satisfaction of the performance obligation. See Economic Development Incentives below and Note 10 — Other Long-Term Liabilities — Long-Term Deferred Revenue.

Economic Development Incentives. Under certain economic development programs, TVA offers incentives to existing and potential power customers in targeted business sectors that make multi-year commitments to invest in the Tennessee Valley. TVA records those incentives as reductions of revenue. Incentives recorded as a reduction to revenue were $73 million and $82 million for the three months ended December 31, 2023 and 2022, respectively. Incentives that have been approved but have not been paid are recorded in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. At December 31, 2023, and September 30, 2023, the outstanding unpaid incentives were $181 million and $188 million, respectively. Incentives that have been paid out may be subject to claw back if the customer fails to meet certain program requirements.

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Research and Development

3 Months Ended

Dec. 31, 2023

Research and Development [Abstract]

Collaborative Arrangement Disclosure

19. Collaborative Arrangement

In 2023, TVA, Ontario Power Generation, BWRX TCA sp. z.o.o., and GE Hitachi Nuclear Energy ("GEH") entered into a multi-party collaborative arrangement to advance the global deployment of the GEH BWRX-300 small modular reactor. GEH is responsible for standard design development. Under the agreement, TVA will contribute up to $88 million for design costs incurred by GEH through 2026. At the time feasibility is determined, TVA will have the right to use the design and may receive additional economic benefits.

Payments pursuant to the agreement are recorded as research and development expense, which is reflected as Operating and maintenance expense on TVA's Consolidated Statement of Operations in the period incurred. TVA recorded $9 million and $16 million of expenses related to this agreement for the three months ended December 31, 2023 and 2022, respectively. TVA also had a $6 million letter of credit posted under this arrangement at December 31, 2023.

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Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Pay vs Performance Disclosure
Net income (loss)	$ 127	$ 101

XML

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The Tennessee Valley Authority ("TVA") prepares its consolidated interim financial statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") for consolidated interim financial information. Accordingly, TVA's consolidated interim financial statements do not include all of the information and notes required by GAAP for annual financial statements. As such, they should be read in conjunction with the audited financial statements for the year ended September 30, 2023, and the notes thereto, which are contained in TVA's Annual Report on Form 10-K for the year ended September 30, 2023 (the "Annual Report"). In the opinion of management, all adjustments (consisting of items of a normal recurring nature) considered necessary for fair presentation are included on the consolidated interim financial statements.

The accompanying consolidated interim financial statements, which have been prepared in accordance with GAAP, include the accounts of TVA and variable interest entities ("VIEs") of which TVA is the primary beneficiary. See Note 9 — Variable Interest Entities. Intercompany balances and transactions have been eliminated in consolidation

Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]

Cash, Cash Equivalents, and Restricted Cash

Cash includes cash on hand, non-interest bearing cash, and deposit accounts. All highly liquid investments with original maturities of three months or less are considered cash equivalents. Cash and cash equivalents that are restricted, as to withdrawal or use under the terms of certain contractual agreements, are recorded in Other long-term assets on the Consolidated Balance Sheets. Restricted cash and cash equivalents include cash held in trusts that are currently restricted for TVA economic development loans and for certain TVA environmental programs in accordance with agreements related to compliance with certain environmental regulations.

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported on the Consolidated Balance Sheets and Consolidated Statements of Cash Flows:

Cash, Cash Equivalents, and Restricted Cash (in millions)
	At December 31, 2023		At September 30, 2023
Cash and cash equivalents	$	498	$	501
Restricted cash and cash equivalents included in Other long-term assets	20		20
Total cash, cash equivalents, and restricted cash	$	518	$	521

Allowance for Uncollectible Accounts

Allowance for Uncollectible Accounts

TVA recognizes an allowance that reflects the current estimate for credit losses expected to be incurred over the life of the financial assets based on historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amounts. The appropriateness of the allowance is evaluated at the end of each reporting period.

To determine the allowance for trade receivables, TVA considers historical experience and other currently available information, including events such as customer bankruptcy and/or a customer failing to fulfill payment arrangements by the due date. TVA's corporate credit department also performs an assessment of the financial condition of customers and the credit quality of the receivables. In addition, TVA reviews other reasonable and supportable forecasts to determine if the allowance for uncollectible amounts should be further adjusted in accordance with the accounting guidance for Current Expected Credit Losses.

To determine the allowance for loans receivables, TVA aggregates loans into the appropriate pools based on the existence of similar risk characteristics such as collateral types and internal assessed credit risks. In situations where a loan exhibits unique risk characteristics and is no longer expected to experience similar risks to the rest of its pool, the loan will be evaluated separately. TVA derives an annual loss rate based on historical loss and then adjusts the rate to reflect TVA's consideration of available information on current conditions and reasonable and supportable future forecasts. This information may include economic and business conditions, default trends, and other internal and external factors. For periods beyond the reasonable and supportable forecast period, TVA uses the current calculated long-term average historical loss rate for the remaining life of the loan portfolio.

The allowance for uncollectible accounts was less than $1 million at both December 31, 2023, and September 30, 2023, for trade accounts receivable. Additionally, loans receivable of $105 million and $104 million at December 31, 2023, and September 30, 2023, respectively, are included in Accounts receivable, net and Other long-term assets, for the current and long-term portions, respectively. Loans receivables are reported net of allowances for uncollectible accounts of $3 million at both December 31, 2023 and September 30, 2023.

Revenue

Pre-Commercial Plant Operations

As part of the process of completing the construction of a generating unit, the electricity produced is used to serve the demands of the electric system. TVA estimates revenues earned during pre-commercial operations at the fair value of the energy delivered based on TVA's hourly incremental dispatch cost. Pre-commercial plant operations began on Paradise Combustion Turbine Units 5-7 in the first quarter of 2024, and the units became operational on December 29, 2023. Estimated revenue of $3 million related to this project was capitalized to offset project costs for the three months ended December 31, 2023. TVA also capitalized related fuel costs for this project of $3 million for the three months ended December 31, 2023.

Depreciation

Depreciation    

TVA accounts for depreciation of its properties using the composite depreciation convention of accounting. Under the composite method, assets with similar economic characteristics are grouped and depreciated as one asset. Depreciation is generally computed on a straight-line basis over the estimated service lives of the various classes of assets. The estimation of asset useful lives requires management judgment, supported by external depreciation studies of historical asset retirement experience. Depreciation rates are determined based on external depreciation studies that are updated approximately every five years, with the latest study implemented during the first quarter of 2022. Depreciation expense was $452 million and $466 million for the three months ended December 31, 2023 and 2022, respectively. See Note 6 — Plant Closures for a discussion of the impact of plant closures.

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Accounting Changes and Error Corrections (Policies)

3 Months Ended

Dec. 31, 2023

Accounting Changes and Error Corrections [Abstract]

Impact of New Accounting Standards and Interpretations

The following are accounting standard updates issued by the Financial Accounting Standards Board that TVA adopted during 2024:

Accounting for Contract Assets and Contract Liabilities from Contracts with Customers
Description	This guidance requires an entity (acquirer) to recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with revenue with customers. It is expected that an acquirer will generally recognize and measure acquired contract assets and contract liabilities in a manner consistent with how the acquiree recognized and measured contract assets and contract liabilities in the acquiree’s financial statements. The entity should apply the standard prospectively to business combinations occurring on or after the effective date of the standard.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

Troubled Debt Restructurings and Vintage Disclosures
Description	This guidance eliminates the recognition and measurement guidance on troubled debt restructuring for creditors that have adopted Financial Instruments-Credit Losses and requires enhanced disclosures about loan modifications for borrowers experiencing financial difficulty. Additionally, the guidance requires public business entities to present current-period gross write-offs by year of origination in their vintage disclosures. The entity should apply the standard prospectively except for the transition method related to the recognition and measurement of troubled debt restructuring. For the transition method, an entity has the option to apply a modified retrospective transition method, resulting in a cumulative-effect adjustment to retained earnings in the period of adoption.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

The following accounting standard has been issued but as of December 31, 2023, was not effective and has not been adopted by TVA:

Improvements to Reportable Segment Disclosures
Description	This guidance improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The amendment requires a public entity to disclose, on an annual and interim basis, significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss. It also requires a public entity that has a single reportable segment to provide all of the disclosures required by the amendment and all existing segment disclosures. The amendment is effective for public entities for fiscal years beginning after December 15, 2023, and interim periods in fiscal years beginning after December 15, 2024. The amendment should be adopted retrospectively unless it is impracticable to do so. Upon adoption, a public entity will adopt the amendment as of the beginning of the earliest period presented.
Effective Date for TVA	October 1, 2024
Effect on the Financial Statements or Other Significant Matters	TVA is currently reviewing and evaluating this standard. TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations, or cash flows.

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Deferred Costs, Capitalized, Prepaid, and Other Assets (Policies)	3 Months Ended
	Dec. 31, 2023
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Derivatives, Methods of Accounting, Hedging Derivatives	Commodity Contract Derivative Assets. TVA enters into certain derivative contracts for natural gas that require physical delivery of the contracted quantity of the commodity as well as certain financial derivative contracts to hedge exposure to the price of natural gas. Commodity contract derivative assets classified as current include deliveries or settlements that will occur within 12 months or less. See Note 13 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.

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Variable Interest Entities (Policies)

3 Months Ended

Dec. 31, 2023

Text Block [Abstract]

Consolidation, Variable Interest Entity, Policy

A VIE is an entity that either (i) has insufficient equity to permit the entity to finance its activities without additional subordinated financial support or (ii) has equity investors who lack the characteristics of owning a controlling financial interest. When TVA determines that it has a variable interest in a VIE, a qualitative evaluation is performed to assess which interest holders have the power to direct the activities that most significantly impact the economic performance of the entity and have the obligation to absorb losses or receive benefits that could be significant to the entity. The evaluation considers the purpose and

design of the business, the risks that the business was designed to create and pass along to other entities, the activities of the business that can be directed and which party can direct them, and the expected relative impact of those activities on the economic performance of the business through its life. TVA has the power to direct the activities of an entity when it has the ability to make key operating and financing decisions, including, but not limited to, capital investment and the issuance of debt. Based on the evaluation of these criteria, TVA has determined it is the primary beneficiary of certain entities and as such is required to account for the VIEs on a consolidated basis.

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Summary of Significant Accounting Policies Cash, Cash Equivalents, and Restricted Cash (Tables)

3 Months Ended

Dec. 31, 2023

Cash and Cash Equivalents [Abstract]

Schedule of Cash and Cash Equivalents

Cash, Cash Equivalents, and Restricted Cash (in millions)
	At December 31, 2023		At September 30, 2023
Cash and cash equivalents	$	498	$	501
Restricted cash and cash equivalents included in Other long-term assets	20		20
Total cash, cash equivalents, and restricted cash	$	518	$	521

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Impact of New Accounting Standards and Interpretations Impact of New Accounting Standards and Interpretations (Tables)

3 Months Ended

Dec. 31, 2023

Accounting Changes and Error Corrections [Abstract]

Schedule of New Accounting Pronouncements and Changes in Accounting Principles

The following are accounting standard updates issued by the Financial Accounting Standards Board that TVA adopted during 2024:

Accounting for Contract Assets and Contract Liabilities from Contracts with Customers
Description	This guidance requires an entity (acquirer) to recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with revenue with customers. It is expected that an acquirer will generally recognize and measure acquired contract assets and contract liabilities in a manner consistent with how the acquiree recognized and measured contract assets and contract liabilities in the acquiree’s financial statements. The entity should apply the standard prospectively to business combinations occurring on or after the effective date of the standard.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

Troubled Debt Restructurings and Vintage Disclosures
Description	This guidance eliminates the recognition and measurement guidance on troubled debt restructuring for creditors that have adopted Financial Instruments-Credit Losses and requires enhanced disclosures about loan modifications for borrowers experiencing financial difficulty. Additionally, the guidance requires public business entities to present current-period gross write-offs by year of origination in their vintage disclosures. The entity should apply the standard prospectively except for the transition method related to the recognition and measurement of troubled debt restructuring. For the transition method, an entity has the option to apply a modified retrospective transition method, resulting in a cumulative-effect adjustment to retained earnings in the period of adoption.
Effective Date for TVA	TVA adopted the standard on October 1, 2023, on a prospective basis.
Effect on the Financial Statements or Other Significant Matters	Adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows.

The following accounting standard has been issued but as of December 31, 2023, was not effective and has not been adopted by TVA:

Improvements to Reportable Segment Disclosures
Description	This guidance improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The amendment requires a public entity to disclose, on an annual and interim basis, significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss. It also requires a public entity that has a single reportable segment to provide all of the disclosures required by the amendment and all existing segment disclosures. The amendment is effective for public entities for fiscal years beginning after December 15, 2023, and interim periods in fiscal years beginning after December 15, 2024. The amendment should be adopted retrospectively unless it is impracticable to do so. Upon adoption, a public entity will adopt the amendment as of the beginning of the earliest period presented.
Effective Date for TVA	October 1, 2024
Effect on the Financial Statements or Other Significant Matters	TVA is currently reviewing and evaluating this standard. TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations, or cash flows.

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Accounts Receivable, Net (Tables)

3 Months Ended

Dec. 31, 2023

Accounts Receivable, after Allowance for Credit Loss [Abstract]

Accounts Receivable, Net

The table below summarizes the types and amounts of TVA's accounts receivable:

Accounts Receivable, Net (in millions)
	At December 31, 2023		At September 30, 2023
Power receivables	$	1,451	$	1,627
Other receivables	142		118
Accounts receivable, net(1)	$	1,593	$	1,745

Note

(1) Allowance for uncollectible accounts was less than $1 million at both December 31, 2023, and September 30, 2023, and therefore is not represented in the table above.

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Inventories, Net (Tables)

3 Months Ended

Dec. 31, 2023

Inventory, Net [Abstract]

Inventories, Net

The table below summarizes the types and amounts of TVA's inventories:

Inventories, Net (in millions)
	At December 31, 2023		At September 30, 2023
Materials and supplies inventory	$	884	$	849
Fuel inventory	354		313
Renewable energy certificates/emissions allowance inventory, net	16		15
Allowance for inventory obsolescence	(72)		(69)
Inventories, net	$	1,182	$	1,108

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Deferred Costs, Capitalized, Prepaid, and Other Assets (Tables)

3 Months Ended

Dec. 31, 2023

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Schedule of Other Current Assets

Other current assets consisted of the following:

Other Current Assets  (in millions)
	At December 31, 2023		At September 30, 2023
Inventory work-in-progress	$	47	$	28
Prepaid software maintenance	36		18
Commodity contract derivative assets	19		21
Prepaid insurance	16		16
Current portion of prepaid long-term service agreements	10		25
Other	24		26
Other current assets	$	152	$	134

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Other Long-Term Assets (Tables)

3 Months Ended

Dec. 31, 2023

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Other Long-Term Assets

The table below summarizes the types and amounts of TVA's other long-term assets:

Other Long-Term Assets (in millions)
	At December 31, 2023		At September 30, 2023
Loans and other long-term receivables, net	$	101	$	97
EnergyRight® receivables, net	46		47
Prepaid long-term service agreements	44		64
Prepaid capital assets	21		28
Commodity contract derivative assets	12		12
Other	88		82
Total other long-term assets	$	312	$	330

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Regulatory Assets and Liabilities (Tables)

3 Months Ended

Dec. 31, 2023

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

Components of regulatory assets and regulatory liabilities are summarized in the table below.

Regulatory Assets and Liabilities (in millions)
	At December 31, 2023		At September 30, 2023
Current regulatory assets
Unrealized losses on interest rate derivatives	$	37	$	31
Unrealized losses on commodity derivatives	213		136
Fuel cost adjustment receivable	—		11
Other current regulatory assets	1		—
Total current regulatory assets	251		178
Non-current regulatory assets
Retirement benefit plans deferred costs	1,438		1,440
Non-nuclear decommissioning costs	2,838		2,922
Unrealized losses on interest rate derivatives	459		272
Nuclear decommissioning costs	543		728
Unrealized losses on commodity derivatives	98		52
Other non-current regulatory assets	175		152
Total non-current regulatory assets	5,551		5,566
Total regulatory assets	$	5,802	$	5,744
Current regulatory liabilities
Fuel cost adjustment tax equivalents	$	190	$	201
Fuel cost adjustment	50		—
Unrealized gains on commodity derivatives	19		21
Total current regulatory liabilities	259		222
Non-current regulatory liabilities
Retirement benefit plans deferred credits	91		95
Unrealized gains on commodity derivatives	12		12
Total non-current regulatory liabilities	103		107
Total regulatory liabilities	$	362	$	329

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Variable Interest Entities (Tables)

3 Months Ended

Dec. 31, 2023

Text Block [Abstract]

Schedule of Variable Interest Entities

The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG at December 31, 2023, and September 30, 2023, as reflected on the Consolidated Balance Sheets, are as follows:

Summary of Impact of VIEs on Consolidated Balance Sheets (in millions)
	At December 31, 2023		At September 30, 2023
Current liabilities
Accrued interest	$	21	$	9
Accounts payable and accrued liabilities	1		1
Current maturities of long-term debt of variable interest entities	35		35
Total current liabilities	57		45
Other liabilities
Other long-term liabilities	17		17
Long-term debt, net
Long-term debt of variable interest entities, net	933		933
Total liabilities	$	1,007	$	995

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Other Long-Term Liabilities (Tables)

3 Months Ended

Dec. 31, 2023

Other Liabilities, Noncurrent [Abstract]

Other Long-Term Liabilities

The table below summarizes the types and amounts of Other long-term liabilities:

Other Long-Term Liabilities (in millions)
	At December 31, 2023		At September 30, 2023
Interest rate swap liabilities	$	782	$	627
Operating lease liabilities	163		93
Currency swap liabilities	112		131
Commodity contract derivative liabilities	98		52
EnergyRight® financing obligation	55		55
Advances for construction	46		56
Long-term deferred revenue	46		45
Long-term deferred compensation	32		41
Other	154		111
Total other long-term liabilities	$	1,488	$	1,211

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Asset Retirement Obligations (Tables)

3 Months Ended

Dec. 31, 2023

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligation Activity

Asset Retirement Obligation Activity (in millions)
	Nuclear		Non-Nuclear		Total
Balance at September 30, 2023	$	3,808	$	3,681	$	7,489	(1)
Settlements	(4)		(59)		(63)
Revisions in estimate	—		78		78
Accretion (recorded as regulatory asset)	43		23		66
Balance at December 31, 2023	$	3,847	$	3,723	$	7,570	(1)

Note

(1) Includes $275 million and $272 million at December 31, 2023, and September 30, 2023, respectively, in Current liabilities.

Revisions to non-nuclear estimates increased the liability balance by $78 million for the three months ended December 31, 2023. The increase was primarily attributable to a change in closure liabilities of $76 million at Cumberland based on scope changes to the interim closure plan and updated cost estimates for activities associated with final closure.

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Debt and Other Obligations (Tables)

3 Months Ended

Dec. 31, 2023

Debt Disclosure [Abstract]

Debt Outstanding

Total debt outstanding at December 31, 2023, and September 30, 2023, consisted of the following:

Debt Outstanding  (in millions)
	At December 31, 2023		At September 30, 2023
Short-term debt
Short-term debt, net of discounts	$	1,042	$	432
Current maturities of power bonds issued at par	1,022		1,022
Current maturities of long-term debt of VIEs issued at par	35		35
Total current debt outstanding, net	2,099		1,489
Long-term debt
Long-term power bonds(1)	17,990		17,970
Long-term debt of VIEs, net	933		933
Unamortized discounts, premiums, issue costs, and other	(123)		(126)
Total long-term debt, net	18,800		18,777
Total debt outstanding	$	20,899	$	20,266

Note

(1) Includes total net exchange gain from currency transactions of $88 million and $109 million at December 31, 2023, and September 30, 2023, respectively.

Debt Securities Activity

Debt Securities Activity

The table below summarizes the long-term debt securities activity for the period from October 1, 2023, to December 31, 2023:

Debt Securities Activity
	Date	Amount (in millions)
Redemptions/Maturities(1)
2009 Series B	December 2023	$	1
Total redemptions/maturities of debt		$	1

Note

(1) All redemptions were at 100 percent of par.

Summary of Long-Term Credit Facilities

Summary of Long-Term Credit Facilities At December 31, 2023 (in millions)
Maturity Date	Facility Limit		Letters of Credit Outstanding		Cash Borrowings		Availability
February 2025	$	500	$	223	$	—	$	277
March 2026	150		38		—		112
September 2026	1,000		112		—		888
March 2027	1,000		96		—		904
Total	$	2,650	$	469	$	—	$	2,181

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Risk Management Activities and Derivative Transactions (Tables)

3 Months Ended

Dec. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Summary of Derivative Instruments That Receive Hedge Accounting Treatment

The following tables summarize the accounting treatment that certain of TVA's financial derivative transactions receive:

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 1)  Amount of Mark-to-Market Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) (in millions)
			Three Months Ended December 31
Derivatives in Cash Flow Hedging Relationship	Objective of Hedge Transaction	Accounting for Derivative Hedging Instrument	2023		2022
Currency swaps	To protect against changes in cash flows caused by changes in foreign currency exchange rates (exchange rate risk)	Unrealized gains and losses are recorded in AOCI and reclassified to Interest expense to the extent they are offset by gains and losses on the hedged transaction	$	20	$	71

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2)(1) Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Interest Expense (in millions)
	Three Months Ended December 31
Derivatives in Cash Flow Hedging Relationship	2023		2022
Currency swaps	$	19	$	34

Note

(1) There were no amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $3 million of gains from Accumulated other comprehensive income (loss) ("AOCI") to Interest expense within the next 12 months to offset amounts anticipated to be recorded in Interest expense related to the forecasted exchange loss on the debt.

^[1]

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment Amount of Gain (Loss) Recognized in Income on Derivatives(1) (in millions)
			Three Months Ended December 31
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2023		2022
Interest rate swaps	To fix short-term debt variable rate to a fixed rate (interest rate risk)	Mark-to-market gains and losses are recorded as regulatory liabilities and assets, respectively Realized gains and losses are recognized in Interest expense when incurred during the settlement period and are presented in operating cash flow	$	(8)	$	(15)
Commodity derivatives under the FHP	To protect against fluctuations in market prices of purchased commodities (price risk)	Mark-to-market gains and losses are recorded as regulatory liabilities and assets, respectively Realized gains and losses are recognized in Fuel expense or Purchased power expense as the contracts settle to match the delivery period of the underlying commodity(2)	(54)		(19)

Notes

(1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the three months ended December 31, 2023 and for the three months ended December 31, 2022.

(2) Of the amount recognized for the three months ended December 31, 2023, $44 million and $10 million were reported in Fuel expense and Purchased power expense, respectively. Of the amount recognized for three months ended December 31, 2022, $15 million and $4 million were reported in Fuel expense and Purchased power expense, respectively.

Fair Value of TVA Derivatives

Fair Values of TVA Derivatives (in millions)
	At December 31, 2023			At September 30, 2023
Derivatives That Receive Hedge Accounting Treatment:
	Balance		Balance Sheet Presentation	Balance		Balance Sheet Presentation
Currency swaps
£250 million Sterling	$	(56)	Accounts payable and accrued liabilities $(5); Other long-term liabilities $(51)	$	(72)	Accounts payable and accrued liabilities $(6); Other long-term liabilities $(66)
£150 million Sterling	(65)		Accounts payable and accrued liabilities $(4); Other long-term liabilities $(61)	(69)		Accounts payable and accrued liabilities $(4); Other long-term liabilities $(65)
Derivatives That Do Not Receive Hedge Accounting Treatment:
	Balance		Balance Sheet Presentation	Balance		Balance Sheet Presentation
Interest rate swaps
$1.0 billion notional	$	(607)	Accounts payable and accrued liabilities $(22); Accrued interest $(6); Other long-term liabilities $(579)	$	(499)	Other current assets $1; Accrued interest $(27); Other long-term liabilities $(473)
$476 million notional	(211)		Accounts payable and accrued liabilities $(8); Other long-term liabilities $(203)	(159)		Other current assets $3; Accrued interest $(8); Other long-term liabilities $(154)
Commodity contract derivatives	29		Other current assets $19; Other long-term assets $12; Accounts payable and accrued liabilities $(1); Other long-term liabilities $(1)	31		Other current assets $21; Other long-term assets $12; Accounts payable and accrued liabilities $(1); Other long-term liabilities $(1)
Commodity derivatives under the FHP	(309)		Accounts payable and accrued liabilities $(212); Other long-term liabilities $(97)	(186)		Accounts payable and accrued liabilities $(135); Other long-term liabilities $(51)

Commodity Contract Derivatives

Commodity Contract Derivatives
	At December 31, 2023				At September 30, 2023
	Number of Contracts	Notional Amount	Fair Value (MtM) (in millions)		Number of Contracts	Notional Amount	Fair Value (MtM) (in millions)
Natural gas contract derivatives	45	366 million mmBtu	$	29	54	318 million mmBtu	$	31

Offsetting Assets and Liabilities

The amounts of TVA's derivative instruments as reported on the Consolidated Balance Sheets are shown in the table below:

Derivative Assets and Liabilities(1) (in millions)
	At December 31, 2023		At September 30, 2023
Assets
Commodity contract derivatives	$	31	$	33
Interest rate swaps	—		4
Total derivatives subject to master netting or similar arrangement	$	31	$	37
Liabilities
Currency swaps	$	121	$	141
Interest rate swaps(2)	818		662
Commodity contract derivatives	2		2
Commodity derivatives under the FHP(3)	309		186
Total derivatives subject to master netting or similar arrangement	$	1,250	$	991

Notes

(1) Offsetting amounts include counterparty netting of derivative contracts. Except as discussed below, there were no other material offsetting amounts on TVA's Consolidated Balance Sheets at either December 31, 2023, or September 30, 2023.

(2) Letters of credit of $443 million and $509 million were posted as collateral at December 31, 2023, and September 30, 2023, respectively, to partially secure the

liability positions of one of the interest rate swaps in accordance with the collateral requirements for this derivative.

(3) At December 31, 2023, the gross derivative asset and gross derivative liability were $8 million and $317 million, respectively, with offsetting amounts for each totaling $8 million.

Schedule of Derivative Instruments Commodity Contracts Under FHP

Commodity Derivatives under Financial Hedging Program(1)
	At December 31, 2023					At September 30, 2023
	Number of Contracts	Notional Amount		Fair Value (MtM) (in millions)		Number of Contracts	Notional Amount		Fair Value (MtM) (in millions)
Natural gas
Swap contracts	206	351	million mmBtu	$	(309)	221	388	million mmBtu	$	(186)

Note

(1) Fair value amounts presented are based on the net commodity position with the counterparty. Notional amounts disclosed represent the net value of contractual amounts.

[1] There were no amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $3 million of gains from Accumulated other comprehensive income (loss) ("AOCI") to Interest expense within the next 12 months to offset amounts anticipated to be recorded in Interest expense related to the forecasted exchange loss on the debt.

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Fair Value Measurements (Tables)

3 Months Ended

Dec. 31, 2023

Fair Value Disclosures [Abstract]

Valuation Techniques

The measurement of fair value results in classification into a hierarchy by the inputs used to determine the fair value as follows:

Level 1	—	Unadjusted quoted prices in active markets accessible by the reporting entity for identical assets or liabilities.  Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing.
Level 2	—	Pricing inputs other than quoted market prices included in Level 1 that are based on observable market data and that are directly or indirectly observable for substantially the full term of the asset or liability.  These include quoted market prices for similar assets or liabilities, quoted market prices for identical or similar assets in markets that are not active, adjusted quoted market prices, inputs from observable data such as interest rate and yield curves, volatilities and default rates observable at commonly quoted intervals, and inputs derived from observable market data by correlation or other means.
Level 3	—	Pricing inputs that are unobservable, or less observable, from objective sources.  Unobservable inputs are only to be used to the extent observable inputs are not available.  These inputs maintain the concept of an exit price from the perspective of a market participant and should reflect assumptions of other market participants.  An entity should consider all market participant assumptions that are available without unreasonable cost and effort.  These are given the lowest priority and are generally used in internally developed methodologies to generate management's best estimate of the fair value when no observable market data is available.

Unrealized Investment Gains (Losses)

TVA recorded unrealized gains and losses related to its equity and trading debt securities held during each period as follows:

Unrealized Investment Gains (Losses)(1) (in millions)
		Three Months Ended December 31
Fund	Financial Statement Presentation	2023		2022
NDT	Regulatory assets(2)	$	197	$	136
ART	Regulatory assets(3)	89		69
SERP	Other income, net	7		3
DCP	Other income, net	1		—

Notes

(1) Employee contributions to the RP began in the second quarter of 2023. As of December 31, 2023, the unrealized gains for the RP were less than $1 million, and therefore were not represented in the table above.

(2) Includes $61 million and $20 million of unrealized gains related to NDT equity securities (excluding commingled funds) for the three months ended December 31, 2023 and 2022, respectively.

(3) Includes $18 million and $10 million of unrealized gains related to ART equity securities (excluding commingled funds) for the three months ended December 31, 2023 and 2022, respectively.

Fair Value Measurements

Fair Value Measurements At December 31, 2023 (in millions)
	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Assets
Investments
Equity securities	$	684	$	—	$	—	$	684
Government debt securities(1)	453		69		—		522
Corporate debt securities(2)	—		321		—		321
Mortgage and asset-backed securities	—		37		—		37
Institutional mutual funds	309		—		—		309
Forward debt securities contracts	—		3		—		3
Cash equivalents and other short-term investments	—		163		—		163
Private equity funds measured at net asset value(3)	—		—		—		657
Private real asset funds measured at net asset value(3)	—		—		—		408
Private credit funds measured at net asset value(3)	—		—		—		184
Commingled funds measured at net asset value(3)	—		—		—		1,184
Total investments	1,446		593		—		4,472
Commodity contract derivatives	—		31		—		31
Total	$	1,446	$	624	$	—	$	4,503
	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Liabilities
Currency swaps(4)	$	—	$	121	$	—	$	121
Interest rate swaps	—		818		—		818
Commodity contract derivatives	—		2		—		2
Commodity derivatives under the FHP	—		309		—		309
Total	$	—	$	1,250	$	—	$	1,250

Notes

(1) Includes securities of government-sponsored entities, including $453 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.

(2) Includes both U.S. and foreign debt.

(3) Certain investments that are measured at fair value using the NAV or its equivalent (alternative investments) have not been categorized in the fair value hierarchy. The inputs to these fair value measurements include underlying NAVs, discounted cash flow valuations, comparable market valuations, and adjustments for currency, credit, liquidity, and other risks. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented on the Consolidated Balance Sheets.

(4) TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

Fair Value Measurements At September 30, 2023 (in millions)
	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Assets
Investments
Equity securities	$	608	$	—	$	—	$	608
Government debt securities(1)(2)	391		60		—		451
Corporate debt securities(3)	—		300		—		300
Mortgage and asset-backed securities	—		36		—		36
Institutional mutual funds	288		—		—		288
Forward debt securities contracts	—		11		—		11
Cash equivalents and other short-term investments(2)	—		145		—		145
Private equity funds measured at net asset value(4)	—		—		—		583
Private real asset funds measured at net asset value(4)	—		—		—		387
Private credit funds measured at net asset value(4)	—		—		—		158
Commingled funds measured at net asset value(2)(4)	—		—		—		1,156
Total investments	1,287		552		—		4,123
Interest rate swaps	—		4		—		4
Commodity contract derivatives	—		33		—		33
Total	$	1,287	$	589	$	—	$	4,160
	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Liabilities
Currency swaps(5)	$	—	$	141	$	—	$	141
Interest rate swaps	—		662		—		662
Commodity contract derivatives	—		2		—		2
Commodity derivatives under the FHP	—		186		—		186
Total	$	—	$	991	$	—	$	991

Notes

(1) Includes securities of government-sponsored entities, including $391 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.

(2) At September 30, 2023, $104 million previously classified as Level 1 Cash equivalents and other short-term investments have been reclassified to Level 1 Government debt securities to conform with current year presentation. At September 30, 2023, $21 million previously classified as Level 2 Cash equivalents and other short-term investments have been reclassified to Commingled funds measured at net asset value to conform with current year presentation.

(3) Includes both U.S. and foreign debt.

(4) Certain investments that are measured at fair value using the NAV or its equivalent (alternative investments) have not been categorized in the fair value hierarchy. The inputs to these fair value measurements include underlying NAVs, discounted cash flow valuations, comparable market valuations, and adjustments for currency, credit, liquidity, and other risks. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented on the Consolidated Balance Sheets.

(5)  TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

Estimated Values of Financial Instruments Not Recorded at Fair Value

The estimated values of TVA's financial instruments not recorded at fair value at December 31, 2023, and September 30, 2023, were as follows:

Estimated Values of Financial Instruments Not Recorded at Fair Value (in millions)
		At December 31, 2023				At September 30, 2023
	Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value
EnergyRight® receivables, net (including current portion)	Level 2	$	59	$	55	$	59	$	55
Loans and other long-term receivables, net (including current portion)	Level 2	105		97		104		96
EnergyRight® financing obligations (including current portion)	Level 2	69		81		69		81
Unfunded loan commitments	Level 2	—		—		—		1
Membership interests of VIEs subject to mandatory redemption (including current portion)	Level 2	18		20		18		19
Long-term outstanding power bonds, net (including current maturities)	Level 2	18,889		19,079		18,866		17,963
Long-term debt of VIEs, net (including current maturities)	Level 2	968		987		968		927

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Other Income (Expense), Net (Tables)

3 Months Ended

Dec. 31, 2023

Other Income and Expenses [Abstract]

Other Income (Expense), Net

16.  Other Income, Net

Income and expenses not related to TVA's operating activities are summarized in the following table:

Other Income, Net (in millions)
	Three Months Ended December 31
	2023		2022
Interest income	$	10	$	7
External services	4		3
Gains on investments	9		6
Total other income, net	$	23	$	16

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Benefit Plans (Tables)

3 Months Ended

Dec. 31, 2023

Retirement Benefits [Abstract]

Components of TVA's Benefit Plans

The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the three months ended December 31, 2023 and 2022, were as follows:

Components of TVA's Benefit Plans(1) (in millions)
	For the Three Months Ended December 31
	Pension Benefits				Other Post-Retirement Benefits
	2023		2022		2023		2022
Service cost	$	7	$	9	$	3	$	3
Interest cost	144		142		5		5
Expected return on plan assets	(124)		(123)		—		—
Amortization of prior service credit	(22)		(22)		(4)		(4)
Recognized net actuarial loss (gain)	25		34		(1)		—
Total net periodic benefit cost as actuarially determined	30		40		3		4
Amount expensed due to actions of regulator	—		19		—		—
Total net periodic benefit cost	$	30	$	59	$	3	$	4

Note

(1) The components of net benefit cost other than the service cost component are included in Other net periodic benefit cost on the Consolidated Statements of Operations.

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Revenue (Tables)

3 Months Ended

Dec. 31, 2023

Revenue from Contract with Customer [Abstract]

State [Table Text Block]

TVA's operating revenues by state for the three months ended December 31, 2023 and 2022, are detailed in the table below:

Operating Revenues By State (in millions)
	Three Months Ended December 31
	2023		2022
Alabama	$	408	$	428
Georgia	69		76
Kentucky	177		198
Mississippi	255		278
North Carolina	23		25
Tennessee	1,789		1,941
Virginia	11		13
Subtotal	2,732		2,959
Off-system sales	2		4
Revenue capitalized during pre-commercial plant operations(1)	(3)		—
Revenue from sales of electricity	2,731		2,963
Other revenue	34		52
Total operating revenues	$	2,765	$	3,015

Revenue from External Customers by Products and Services [Table Text Block]

TVA's operating revenues by customer type for the three months ended December 31, 2023 and 2022, are detailed in the table below:

Operating Revenues by Customer Type (in millions)
	Three Months Ended December 31
	2023		2022
Revenue from sales of electricity
Local power companies	$	2,487	$	2,706
Industries directly served	217		225
Federal agencies and other	30		32
Revenue capitalized during pre-commercial plant operations(1)	(3)		—
Revenue from sales of electricity	2,731		2,963
Other revenue	34		52
Total operating revenues	$	2,765	$	3,015

Schedule of Long-term Contracts for Purchase of Electric Power

The number of LPCs by contract arrangement, the revenues derived from such arrangements for the three months ended December 31, 2023, and the percentage those revenues comprised of TVA's total operating revenues for the same period, are summarized in the table below:

TVA Local Power Company Contracts At or for the Three Months Ended December 31, 2023
Contract Arrangements(1)	Number of LPCs	Revenue from Sales of Electricity to LPCs (in millions)		Percentage of Total Operating Revenues
20-year termination notice	147	$	2,156	78.0	%
5-year termination notice	6	331		12.0	%
Total	153	$	2,487	90.0	%

Note

(1) Ordinarily, the LPCs and TVA have the same termination notice period; however, in a contract with one of the LPCs with a five-year termination notice, TVA has a 10-year termination notice (which becomes a five-year termination notice if TVA loses its discretionary wholesale rate-setting authority). Certain LPCs have five-year termination notices or a shorter period if any act of Congress, court decision, or regulatory change requires or permits that election.

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Revenue Local Power Company Contracts (Tables)

3 Months Ended

Dec. 31, 2023

Long-term Contract for Purchase of Electric Power [Line Items]

Long-term Contracts or Programs Disclosure [Text Block]

The number of LPCs by contract arrangement, the revenues derived from such arrangements for the three months ended December 31, 2023, and the percentage those revenues comprised of TVA's total operating revenues for the same period, are summarized in the table below:

TVA Local Power Company Contracts At or for the Three Months Ended December 31, 2023
Contract Arrangements(1)	Number of LPCs	Revenue from Sales of Electricity to LPCs (in millions)		Percentage of Total Operating Revenues
20-year termination notice	147	$	2,156	78.0	%
5-year termination notice	6	331		12.0	%
Total	153	$	2,487	90.0	%

Note

(1) Ordinarily, the LPCs and TVA have the same termination notice period; however, in a contract with one of the LPCs with a five-year termination notice, TVA has a 10-year termination notice (which becomes a five-year termination notice if TVA loses its discretionary wholesale rate-setting authority). Certain LPCs have five-year termination notices or a shorter period if any act of Congress, court decision, or regulatory change requires or permits that election.

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Accounting Policies Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022
Cash and Cash Equivalents [Line Items]
Cash and Cash Equivalents, at Carrying Value	$ 498	$ 501
Restricted Cash and Cash Equivalents, Noncurrent	20	20
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	$ 518	$ 521	$ 520	$ 520

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Summary of Significant Accounting Policies Allowance for Uncollectible Accounts (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Accounts, Notes, Loans and Financing Receivable [Line Items]
Allowance for uncollectible accounts	$ 1	$ 1
Financing Receivable, after Allowance for Credit Loss	97	96
Loans and Leases Receivable, Allowance	3	3
Reported Value Measurement
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing Receivable, after Allowance for Credit Loss	$ 105	$ 104

XML

Summary of Significant Accounting Policies Revenues (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Pre-commercial Ops - capitalized revenue	$ 3	$ 0
Pre-commercial Ops - Capitalized Fuel	$ 3

XML

Summary of Significant Accounting Policies Depreciation (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Depreciation expense	$ 452	$ 466

XML

Accounts Receivable, Net (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Accounts Receivable, Net
Accounts Receivable, before Allowance for Credit Loss, Current	$ 1,451	$ 1,627
Other receivables	142	118
Allowance for uncollectible accounts	1	1
Accounts receivable, net	$ 1,593	$ 1,745

XML

Inventories, Net (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Inventories, Net
Materials and supplies inventory	$ 884	$ 849
Fuel inventory	354	313
Renewable energy certificates/emission allowance inventory, net	16	15
Allowance for inventory obsolescence	(72)	(69)
Inventories, net	$ 1,182	$ 1,108

XML

Deferred Costs, Capitalized, Prepaid, and Other Assets (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Assets, Miscellaneous, Current	$ 24	$ 26
Other current assets	152	134
Prepaid Insurance	16	16
Prepaid Expense, Current	10	25
Prepaid software maintenance	36	18
Inventory, Work in Process and Raw Materials	$ 47	$ 28

XML

Plant Closures (Details) - USD ($)	3 Months Ended		12 Months Ended	57 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2023	Sep. 30, 2023
Property, Plant and Equipment [Line Items]
Accelerated depreciation				$ 659,000,000
Depreciation expense	$ 452,000,000	$ 466,000,000
Accumulated additional depreciation		$ 36,000,000
Cumberland
Property, Plant and Equipment [Line Items]
Accelerated depreciation	$ 16,000,000
Accumulated additional depreciation			$ 64,000,000

XML

Other Long-Term Assets (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Sep. 30, 2023
Other Long-Term Assets
Loans and other long-term receivables, net	$ 101	$ 97
EnergyRight® receivables, net	55	55
Prepaid Expense, Noncurrent	44	64
Prepaid capital assets	21	28
Total other long-term assets	312	330
Prepaid Expense, Current	10	25
Loans and Leases Receivable, Allowance	3	3
Financing Receivable, after Allowance for Credit Loss, Current	4	7
EnergyRight loan reserve
Other Long-Term Assets
Loans and Leases Receivable, Allowance	1	1
Economic development loan specific loan reserve
Other Long-Term Assets
Loans and Leases Receivable, Allowance	1	1
Economic Development Loan Collective Reserve
Other Long-Term Assets
Loans and Leases Receivable, Allowance	1	1
Accounts Receivable [Member]
Other Long-Term Assets
EnergyRight® receivables, net	13	12
Other long-term assets
Other Long-Term Assets
EnergyRight® receivables, net	46	47
Other	88	82
Other long-term assets
Other Long-Term Assets
Commodity Contract Asset, Noncurrent	$ 12	$ 12
Energy Right
Other Long-Term Assets
Number of days in default	180 days
Energy Right | Minimum
Other Long-Term Assets
Debt Instrument, Term	5 years
Energy Right | Maximum
Other Long-Term Assets
Debt Instrument, Term	10 years

XML

Regulatory Assets and Liabilities (Details) $ in Millions	Dec. 31, 2023 USD ($)	Sep. 30, 2023 USD ($)
Regulatory Assets and Liabilities
Current regulatory assets	$ 251	$ 178
Non-current regulatory assets	5,551	5,566
Regulatory assets	5,802	5,744
Current regulatory liabilities	259	222
Regulatory Liability, Noncurrent	103	107
Regulatory Liabilities	362	329
Fair value	$ 98	$ 52
Commodity Contract Derivatives
Regulatory Assets and Liabilities
Number of contracts	45	54
Derivative, Nonmonetary Notional Amount	366,000,000	318,000,000
Fair value	$ 29	$ 31
Fuel cost adjustment tax equivalents
Regulatory Assets and Liabilities
Current regulatory liabilities	190	201
Fuel cost adjustment receivable/liability
Regulatory Assets and Liabilities
Current regulatory liabilities	50	0
Unrealized gains/losses on commodity derivatives
Regulatory Assets and Liabilities
Current regulatory liabilities	19	21
Regulatory Liability, Noncurrent	12	12
Postretirement Benefit Costs
Regulatory Assets and Liabilities
Regulatory Liability, Noncurrent	91	95
Unrealized losses on interest rate derivatives [Member]
Regulatory Assets and Liabilities
Current regulatory assets	37	31
Non-current regulatory assets	459	272
Unrealized gains/losses on commodity derivatives
Regulatory Assets and Liabilities
Current regulatory assets	213	136
Non-current regulatory assets	98	52
Fuel cost adjustment receivable/liability
Regulatory Assets and Liabilities
Current regulatory assets	0	11
Pension Costs [Member]
Regulatory Assets and Liabilities
Non-current regulatory assets	1,438	1,440
Nuclear desommissioning costs [Member]
Regulatory Assets and Liabilities
Non-current regulatory assets	543	728
Non-nuclear decommissioning [Member]
Regulatory Assets and Liabilities
Non-current regulatory assets	2,838	2,922
Other non-current regulatory assets [Member]
Regulatory Assets and Liabilities
Non-current regulatory assets	175	152
Other Regulatory Assets (Liabilities)
Regulatory Assets and Liabilities
Current regulatory assets	$ 1	$ 0

XML

Variable Interest Entities Variable Interest Entities (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2023	Sep. 30, 2013	Sep. 30, 2012
Variable Interest Entities
Other long-term liabilities	$ 1,488		$ 1,211
Accrued interest	21		9
VIE Financing
Face amount	$ 40			$ 360
Financial instruments subject to mandatory redemption, interest rate, stated percentage	7.00%
Liabilities
Current maturities of long-term debt of variable interest entities	$ 35		35
Long-term debt of variable interest entities, net	933		933
Liabilities, Current	5,352		4,873
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities
Other long-term liabilities	17		17
Liabilities	1,007		995		$ 1,000
Liabilities
Liabilities, Current	57		45
Interest Expense	12	$ 12
Accounts Payable and Accrued Liabilities	$ 1		$ 1
JSCCG
VIE Financing
Face amount					900
Holdco
VIE Financing
Face amount					$ 100
SCCG
VIE Financing
Debt and Lease Obligation				$ 400

XML

Other Long-Term Liabilities (Details) - USD ($) $ in Millions		Dec. 31, 2023	Sep. 30, 2023
Other Long-Term Liabilities
Deferred Revenue, Noncurrent		$ 46	$ 45
Interest Rate Derivative Liabilities, at Fair Value		818	662
Operating Lease, Liability, Noncurrent		163	93
Currency swap liabilities	[1]	121	141
Fair value		98	52
EnergyRight® financing obligation		(81)	(81)
Deferred Compensation Liability, Classified, Noncurrent		32	41
Other long-term liabilities		1,488	1,211
Regulatory Liability, Noncurrent		103	107
Deferred Compensation Liability, Current		32	65
Deferred Revenue, Current		23	21
Operating Lease, Liability, Current		81	71
Operating Lease, Liability, Current		81	71
Accounts payable and accrued liabilities
Other Long-Term Liabilities
EnergyRight® financing obligation		(14)	(14)
Customer Advances for Construction		60	39
Other long-term liabilities
Other Long-Term Liabilities
Interest Rate Derivative Liabilities, at Fair Value		782	627
Currency swap liabilities		112	131
EnergyRight® financing obligation		(55)	(55)
Other		154	111
Customer Advances for Construction		$ 46	$ 56

[1] TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

XML

Asset Retirement Obligations (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Sep. 30, 2023
Asset Retirement Obligations
Asset Retirement Obligation, Period Increase (Decrease)	$ 81
Amortization and Depreciation of Decontaminating and Decommissioning Assets	47
Asset Retirement Obligation, Beginning Balance	7,489
Settlements	(63)
Asset Retirement Obligation, Revision of Estimate	78
Accretion (recorded as regulatory asset)	66
Asset Retirement Obligation, Ending Balance	7,570
Current portion of ARO	(275)	$ (272)
Changes in closure liabilities	76
Nuclear
Asset Retirement Obligations
Asset Retirement Obligation, Beginning Balance	3,808
Settlements	(4)
Asset Retirement Obligation, Revision of Estimate	0
Accretion Expense, Including Asset Retirement Obligations	43
Asset Retirement Obligation, Ending Balance	3,847
Non-nuclear
Asset Retirement Obligations
Asset Retirement Obligation, Beginning Balance	3,681
Settlements	(59)
Asset Retirement Obligation, Revision of Estimate	78
Accretion (recorded as regulatory asset)	23
Asset Retirement Obligation, Ending Balance	$ 3,723

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Debt and Other Obligations Debt Outstanding (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Short-term debt
Short-term debt, net	$ 1,042	$ 432
Current maturities of power bonds	1,022	1,022
Current maturities of long-term debt of variable interest entities	35	35
Debt, Current	2,099	1,489
Long-term debt
Long-term power bonds	17,990	17,970
Unamortized discounts, premiums, issues costs, and other	123	126
Total long-term debt, net	18,800	18,777
Total outstanding debt	20,899	20,266
Long-term debt of variable interest entities, net	933	933
Net exchange gain from currency transaction, noncurrent	$ 88	$ 109

XML

Debt and Other Obligations Debt Securities Activity (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023		Dec. 31, 2022	Sep. 30, 2023
Debt Instrument
Total long-term debt, net	$ 18,800			$ 18,777
Redemptions and repurchases of power bonds	1	[1]	$ 1
Amount of letters of credit outstanding	6
Long-term power bonds, net	$ 17,867			$ 17,844
Total
Debt Instrument
Percent of par value	100.00%
2009 Series B June Payment
Debt Instrument
Redemptions and repurchases of power bonds	$ 1

[1] (1) All redemptions were at 100 percent of par.

XML

Debt and Other Obligations Credit Facility Agreements (Details)

3 Months Ended

Dec. 31, 2023

USD ($)

Credit_facilities

Sep. 30, 2023

USD ($)

Line of Credit Facility [Line Items]

Summary of Long-Term Credit Facilities

Summary of Long-Term Credit Facilities At December 31, 2023 (in millions)
Maturity Date	Facility Limit		Letters of Credit Outstanding		Cash Borrowings		Availability
February 2025	$	500	$	223	$	—	$	277
March 2026	150		38		—		112
September 2026	1,000		112		—		888
March 2027	1,000		96		—		904
Total	$	2,650	$	469	$	—	$	2,181

Borrowings under U.S. Treasury credit facility

$ 0

February 2022 Credit Facility

1,000,000,000

Amount of letters of credit outstanding for credit facilities

6,000,000

Line of Credit

Line of Credit Facility [Line Items]

Current borrowing capacity for credit facilities

150,000,000

Revolving Credit Facilities

Line of Credit Facility [Line Items]

Current borrowing capacity for credit facilities

$ 2,650,000,000

Number of revolving credit facilities | Credit_facilities

4

December 2019 Credit Facility

$ 150,000,000

June 2020 Credit Facility

500,000,000

September 2020 Credit Facility

1,000,000,000

Cash Borrowings-December 2019 Credit Facility

0

Cash Borrowings-June 2020 Credit Facility

0

Cash Borrowings-September 2020 Credit Facility

0

Total Cash Borrowings for Credit Facilities

0

Remaining Availability, December 2019 Credit Facility

112,000,000

Remaining Availability, February 2022 Credit Facility

904,000,000

Long-term Line of Credit, Borrowings 3

0

Remaining Availability, June 2020 Credit Facility

277,000,000

Remaining Availability, September 2020 Credit Facility

888,000,000

Total Remaining Availability for Credit Facilities

2,181,000,000

Letter of Credit

Line of Credit Facility [Line Items]

Letters of Credit Outstanding, Amount 1

223,000,000

Letter of Credit Outstanding, December 2019 Credit Facility

38,000,000

Letter of Credit Outstanding, February 2022 Credit Facility

96,000,000

Letter of Credit Outstanding, September 2020 Credit Facility

112,000,000

Amount of letters of credit outstanding for credit facilities

$ 469,000,000

$ 535,000,000

XML

Risk Management Activities and Derivative Transactions Derivative Instruments That Receive Hedge Accounting Treatment (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Summary of Derivative Instruments That Receive Hedge Accounting Treatment
Reclassification to earnings from cash flow hedges in the next 12 months	$ (3)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, after Tax	19	$ 34	[1]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, after Tax	20	71
Fuel Expense | Commodity Contract under FHP
Summary of Derivative Instruments That Receive Hedge Accounting Treatment
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	44	15
Purchased Power Expense | Commodity Contract under FHP
Summary of Derivative Instruments That Receive Hedge Accounting Treatment
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 10	$ 4

[1] There were no amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $3 million of gains from Accumulated other comprehensive income (loss) ("AOCI") to Interest expense within the next 12 months to offset amounts anticipated to be recorded in Interest expense related to the forecasted exchange loss on the debt.

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Risk Management Activities and Derivative Transactions Derivative Instruments That Do Not Receive Hedge Accounting Treatment (Details)	3 Months Ended
	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)		Sep. 30, 2023 USD ($)
Derivative
Change in Unrealized gains (losses) on Interest Rate Derivatives	$ (189,000,000)	$ 14,000,000
Fair value	98,000,000			$ 52,000,000
Increase (Decrease) in Derivative Assets	123,000,000
Interest Rate Swap
Derivative
Amount recognized for unrealized gains (losses)	0
Interest Rate Swap | Other Regulatory Assets (Liabilities)
Derivative
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ (8,000,000)	(15,000,000)	[1]
Commodity Contract Derivatives
Derivative
Number of contracts	45			54
Derivative, Nonmonetary Notional Amount	366,000,000			318,000,000
Fair value	$ 29,000,000			$ 31,000,000
Derivative, Term of Contract	2 years
Derivative, Term of Contract	2 years
Commodity Contract under FHP
Derivative
Number of contracts	206			221
Derivative, Nonmonetary Notional Amount	351			388
Fair value	$ (309,000,000)			$ (186,000,000)
Derivative, Term of Contract	4 years
Derivative, Term of Contract	4 years
Commodity Contract under FHP | Other Regulatory Assets (Liabilities)
Derivative
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ (54,000,000)	$ (19,000,000)

[1] All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the three months ended December 31, 2023 and for the three months ended December 31, 2022. (2) Of the amount recognized for the three months ended December 31, 2023, $44 million and $10 million were reported in Fuel expense and Purchased power expense, respectively. Of the amount recognized for three months ended December 31, 2022, $15 million and $4 million were reported in Fuel expense and Purchased power expense, respectively.

XML

Risk Management Activities and Derivative Transactions Fair Values of TVA Derivatives (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Derivatives, Fair Value
Forward Contract Derivative Asset, at Fair Value	$ 3	$ 11
Fair value	98	52
250 million Sterling currency swap
Derivatives, Fair Value
Fair value	(56)	(72)
250 million Sterling currency swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(51)	(66)
250 million Sterling currency swap | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	(5)	(6)
150 million Sterling currency swap
Derivatives, Fair Value
Fair value	(65)	(69)
150 million Sterling currency swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(61)	(65)
150 million Sterling currency swap | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	(4)	(4)
$1.0 billion notional interest rate swap
Derivatives, Fair Value
Fair value	(607)	(499)
$1.0 billion notional interest rate swap | Other current assets
Derivatives, Fair Value
Fair value		1
$1.0 billion notional interest rate swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(579)	(473)
$1.0 billion notional interest rate swap | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	(22)
$1.0 billion notional interest rate swap | Interest payable, current
Derivatives, Fair Value
Fair value	(6)	(27)
Commodity contract derivatives
Derivatives, Fair Value
Fair value	29	31
Commodity contract derivatives | Other long-term assets
Derivatives, Fair Value
Fair value	12	12
Commodity contract derivatives | Other current assets
Derivatives, Fair Value
Fair value	19	21
Commodity contract derivatives | Other long-term liabilities
Derivatives, Fair Value
Fair value	(1)	(1)
Commodity contract derivatives | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	(1)	(1)
Commodity Contract under FHP
Derivatives, Fair Value
Fair value	(309)	(186)
Gross amounts of recognized liabilities	317
Commodity Contract under FHP | Other long-term liabilities
Derivatives, Fair Value
Fair value	(97)	(51)
Commodity Contract under FHP | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	(212)	(135)
$476 million notational interest rate swap
Derivatives, Fair Value
Fair value	(211)	(159)
$476 million notational interest rate swap | Other current assets
Derivatives, Fair Value
Fair value		3
$476 million notational interest rate swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(203)	(154)
$476 million notational interest rate swap | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	(8)
$476 million notational interest rate swap | Interest payable, current
Derivatives, Fair Value
Fair value		(8)
Fair Value, Inputs, Level 2
Derivatives, Fair Value
Forward Contract Derivative Asset, at Fair Value	$ 3	$ 11

XML

Risk Management Activities and Derivative Transactions Currency Swaps Outstanding (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($)	Mar. 31, 2023 Bond_issues
Derivative
Number of currency swaps outstanding | Bond_issues		2
Amount of letters of credit outstanding for credit facilities	$ 6
Associated TVA bond issues currency exposure	$ 400
Minimum | 250 million Sterling currency swap
Derivative
Expiration date range of swaps	2032
Maximum | 150 million Sterling currency swap
Derivative
Expiration date range of swaps	2043

XML

Risk Management Activities and Derivative Transactions Derivatives Under FTP (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Derivative
Forward Contract Derivative Asset, at Fair Value	$ 3	$ 11
Fair value	98	52
Commodity Contract under FHP
Derivative
Fair value	(309)	(186)
Fair Value, Inputs, Level 2
Derivative
Forward Contract Derivative Asset, at Fair Value	$ 3	$ 11

XML

Risk Management Activities and Derivative Transactions Offsetting of Derivative Assets (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Offsetting Assets [Line Items]
Derivative Asset, Subject to Master Netting Arrangement, after Offset	$ 31	$ 37
Amount of letters of credit outstanding for credit facilities	6
Forward Contract Derivative Asset, at Fair Value	3	11
Derivative Liability, Subject to Master Netting Arrangement, after Offset	1,250	991
Offsetting Derivative Assets [Abstract]
Derivative Asset, Fair Value, Gross Liability	8
Letter of Credit
Offsetting Assets [Line Items]
Amount of letters of credit outstanding for credit facilities	469	535
Currency Swap
Offsetting Assets [Line Items]
Derivative Liability, Subject to Master Netting Arrangement, after Offset	121	141
Commodity Contract under FHP
Offsetting Assets [Line Items]
Derivative Liability, Subject to Master Netting Arrangement, after Offset	309	186
Offsetting Derivative Assets [Abstract]
Derivative Asset, Subject to Master Netting Arrangement, before Offset	8
Gross amounts of recognized liabilities	317
Interest Rate Swap
Offsetting Assets [Line Items]
Derivative Asset, Subject to Master Netting Arrangement, after Offset	0	4
Derivative Liability, Subject to Master Netting Arrangement, after Offset	818	662
Commodity Contract Derivatives
Offsetting Assets [Line Items]
Derivative Asset, Subject to Master Netting Arrangement, after Offset	31	33
Derivative Liability, Subject to Master Netting Arrangement, after Offset	2	2
Fair Value, Inputs, Level 2
Offsetting Assets [Line Items]
Forward Contract Derivative Asset, at Fair Value	$ 3	$ 11

XML

Risk Management Activities and Derivative Transactions Offsetting for Derivative Liabilities (Details) $ in Millions	Dec. 31, 2023 USD ($)	Sep. 30, 2023 USD ($)	Mar. 31, 2023 Bond_issues
Offsetting Liabilities [Line Items]
Number of currency swaps outstanding | Bond_issues			2
Accounts Receivable, before Allowance for Credit Loss, Current	$ 1,451	$ 1,627
Amount of letters of credit outstanding	6
Forward Contract Derivative Asset, at Fair Value	3	11
Letter of Credit
Offsetting Liabilities [Line Items]
Amount of letters of credit outstanding	469	535
Interest Swap Collateral
Offsetting Liabilities [Line Items]
Amount of letters of credit outstanding	443
Fair Value, Inputs, Level 2
Offsetting Liabilities [Line Items]
Forward Contract Derivative Asset, at Fair Value	$ 3	$ 11

XML

Risk Management Activities and Derivative Transactions Collateral (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Derivative
Amount of letters of credit outstanding	$ 6
Forward Contract Derivative Asset, at Fair Value	3	$ 11
Likely cash collateral obligation increase	22
Derivative Liability, Subject to Master Netting Arrangement, after Offset	1,250	991
Collateralized Securities [Member]
Derivative
Derivative, Collateral, Right to Reclaim Cash	537
Credit Risk
Derivative
Derivative Liability, Subject to Master Netting Arrangement, after Offset	1,300
Letter of Credit
Derivative
Amount of letters of credit outstanding	469	535
Interest Swap Collateral
Derivative
Amount of letters of credit outstanding	443
Interest rate swap collateral
Derivative
Amount of letters of credit outstanding		509
Fair Value, Inputs, Level 2
Derivative
Forward Contract Derivative Asset, at Fair Value	$ 3	$ 11

XML

Risk Management Activities and Derivative Transactions Counterparty Credit Risk (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($) Customers	Sep. 30, 2023 USD ($)
Derivative
Accounts Receivable, before Allowance for Credit Loss, Current | $	$ 1,451	$ 1,627
Two Largest Customer Percentage of Total Operating Revenue	1600.00%
Moody's, A1 Rating [Member]
Derivative
Natural Gas Banking Counterparties Credit Rating	A1
Moody's, B1 Rating [Member]
Derivative
Natural Gas Banking Counterparties Credit Rating	B1
Moody's, A2 Rating
Derivative
Banking Counterparties Credit Rating	A2
Credit of Customers
Derivative
Number of customers that represent the percent of sales	2
Number of customers that represent the percent of sales	2

XML

Risk Management Activities and Derivative Transactions Cash Flow from Hedging (Details) $ in Millions	Dec. 31, 2023 USD ($)
Cash Flow from Hedging [Abstract]
Associated bond issues currency exposure	$ 400

XML

Fair Value Measurements Fair Value Measurements - Investments (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($) Units	Dec. 31, 2022 USD ($)	Sep. 30, 2023 USD ($)
Investment Gains (Losses)
Financing Receivable, after Allowance for Credit Loss	$ 97		$ 96
Period of time where the investor contributes capital to an investment in a private partnership - minimum | Units	3
Period of time where the investor contributes capital to an investment in a private partnership - maximum | Units	4
Minimum investment period | Units	10
Number of readily available quoted exchange prices for the investments	0
Investment funds	$ 4,472		$ 4,123
NDT [Member]
Investment Gains (Losses)
Investment funds	3,000
ART [Member]
Investment Gains (Losses)
Investment funds	1,300
LTDCP [Member]
Investment Gains (Losses)
Unrealized gains (losses) on investments	(1)	$ 0
SERP
Investment Gains (Losses)
Unrealized gains (losses) on investments	(7)	(3)
ART [Member]
Investment Gains (Losses)
Unrealized gains (losses) on investments	(89)	(69)
NDT [Member]
Investment Gains (Losses)
Unrealized gains (losses) on investments	(197)	$ (136)
Real Estate Funds | NDT [Member]
Investment Gains (Losses)
NDT unfunded commitments related to private equity and real estate	110
Real Estate Funds | ART [Member]
Investment Gains (Losses)
NDT unfunded commitments related to private equity and real estate	54
Private Equity Funds [Member] | NDT [Member]
Investment Gains (Losses)
NDT unfunded commitments related to private equity and real estate	296
Private Equity Funds [Member] | ART [Member]
Investment Gains (Losses)
NDT unfunded commitments related to private equity and real estate	122
Private Credit [Member] | NDT [Member]
Investment Gains (Losses)
NDT unfunded commitments related to private equity and real estate	88
Private Credit [Member] | ART [Member]
Investment Gains (Losses)
NDT unfunded commitments related to private equity and real estate	$ 47

XML

Fair Value Measurements Fair Value Measurements - Nonperformance Risk (Details) $ in Millions	Dec. 31, 2023 USD ($)
Nonperformance Risk
Derivative Credit Risk Valuation Adjustment, Derivative Assets	$ 1
Derivative Credit Risk Valuation Adjustment, Derivative Liabilities	$ 1

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Fair Value Measurements Fair Value Measurements (Details) - USD ($) $ in Millions		3 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Financing Receivable, after Allowance for Credit Loss		$ 97		$ 96
Investments
Government debt securities		522		451
Corporate debt securities		321		300
Mortgage and asset-backed securities		37		36
Institutional mutual funds		309		288
Forward debt securities contracts		3		11
Private credit measured at net asset value		184		158
Private equity funds measured at net asset value(1)		657		583	[1]
Private real estate funds measured at net asset value(1)		408		387	[1]
Commingled funds measured at net asset value(1)		1,184		1,156	[1]
Total investments		4,472		4,123
Commodity contract derivatives		31		33
Total		4,503		4,160
Liabilities
Currency swaps	[2]	121		141
Interest rate swaps		818		662
Commodity contract derivatives		2		2
Total		1,250		991
Equity Securities, FV-NI		684		608
Cash, Cash Equivalents, and Short-Term Investments		163		145
Interest Rate Derivative Assets, at Fair Value				4
Government debt securities reclassed				104
Commingled funds reclassed				21
Commodity Contract under FHP
Liabilities
Derivative Liability, Not Subject to Master Netting Arrangement		309		186
NDT [Member]
Liabilities
Debt and Equity Securities, Unrealized Gain (Loss)		61	$ 20
Debt and Equity Securities, Unrealized Gain (Loss)		61	20
ART [Member]
Liabilities
Debt and Equity Securities, Unrealized Gain (Loss)		18	10
Debt and Equity Securities, Unrealized Gain (Loss)		18	$ 10
RP
Liabilities
Debt and Equity Securities, Unrealized Gain (Loss)		1
Debt and Equity Securities, Unrealized Gain (Loss)		1
Fair Value, Inputs, Level 1
Investments
Government debt securities		453		391
Corporate debt securities		0		0
Mortgage and asset-backed securities		0		0
Institutional mutual funds		309		288
Forward debt securities contracts		0		0
Private credit measured at net asset value		0		0
Private equity funds measured at net asset value(1)		0		0	[1]
Private real estate funds measured at net asset value(1)		0		0	[1]
Commingled funds measured at net asset value(1)		0		0	[1]
Total investments		1,446		1,287
Commodity contract derivatives		0		0
Total		1,446		1,287
Liabilities
Currency swaps		0		0	[2]
Interest rate swaps		0		0
Commodity contract derivatives		0		0
Total		0		0
Equity Securities, FV-NI		684		608
Cash, Cash Equivalents, and Short-Term Investments		0		0
Interest Rate Derivative Assets, at Fair Value				0
Fair Value, Inputs, Level 1 | Commodity Contract under FHP
Liabilities
Derivative Liability, Not Subject to Master Netting Arrangement		0		0
Fair Value, Inputs, Level 2
Investments
Government debt securities		69		60
Corporate debt securities		321		300
Mortgage and asset-backed securities		37		36
Institutional mutual funds		0		0
Forward debt securities contracts		3		11
Private credit measured at net asset value		0		0
Private equity funds measured at net asset value(1)		0		0	[1]
Private real estate funds measured at net asset value(1)		0		0	[1]
Commingled funds measured at net asset value(1)		0		0	[1]
Total investments		593		552
Commodity contract derivatives		31		33
Total		624		589
Liabilities
Currency swaps		121		141	[2]
Interest rate swaps		818		662
Commodity contract derivatives		2		2
Total		1,250		991
Equity Securities, FV-NI		0		0
Cash, Cash Equivalents, and Short-Term Investments		163		145
Interest Rate Derivative Assets, at Fair Value				4
Fair Value, Inputs, Level 2 | Commodity Contract under FHP
Liabilities
Derivative Liability, Not Subject to Master Netting Arrangement		309		186
Fair Value, Inputs, Level 3
Investments
Government debt securities		0		0
Corporate debt securities		0		0
Mortgage and asset-backed securities		0		0
Institutional mutual funds		0		0
Forward debt securities contracts		0		0
Private credit measured at net asset value		0		0
Private equity funds measured at net asset value(1)		0		0	[1]
Private real estate funds measured at net asset value(1)		0		0	[1]
Commingled funds measured at net asset value(1)		0		0	[1]
Total investments		0		0
Commodity contract derivatives		0		0
Total		0		0
Liabilities
Currency swaps		0		0	[2]
Interest rate swaps		0		0
Commodity contract derivatives		0		0
Total		0		0
Equity Securities, FV-NI		0		0
Cash, Cash Equivalents, and Short-Term Investments		0		0
Interest Rate Derivative Assets, at Fair Value				0
Fair Value, Inputs, Level 3 | Commodity Contract under FHP
Liabilities
Derivative Liability, Not Subject to Master Netting Arrangement		$ 0		$ 0

[1] Certain investments that are measured at fair value using the NAV or its equivalent (alternative investments) have not been categorized in the fair value hierarchy. The inputs to these fair value measurements include underlying NAVs, discounted cash flow valuations, comparable market valuations, and adjustments for currency, credit, liquidity, and other risks. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented on the Consolidated Balance Sheets. (4) TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

[2] TVA records currency swaps net of cash collateral received from or paid to the counterparty if applicable, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 13 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.

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Fair Value Measurements Fair Value Measurements Using Significant Unobservable Inputs (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contract derivatives	$ 31	$ 33
Commodity contract derivatives	2	2
Fair Value, Inputs, Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contract derivatives	0	0
Commodity contract derivatives	$ 0	$ 0

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Fair Value Measurements Estimated Values of Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Estimated Values of Financial Intruments Not Recorded at Fair Value
EnergyRight® receivables, net (including current portion)	$ 55	$ 55
Loans and other long-term receivables, net (including current portion)	97	96
EnergyRight® financing obligations (including current portion)	81	81
Unfunded loan commitments	0	1
Membership interests of VIEs subject to mandatory redemption (including current portion)	20	19
Long-term outstanding power bonds, net (including current maturities)	19,079	17,963
Long-term debt of VIEs, net (including current maturities)	987	927
Reported Value Measurement
Estimated Values of Financial Intruments Not Recorded at Fair Value
EnergyRight® receivables, net (including current portion)	59	59
Loans and other long-term receivables, net (including current portion)	105	104
EnergyRight® financing obligations (including current portion)	69	69
Unfunded loan commitments	0	0
Membership interests of VIEs subject to mandatory redemption (including current portion)	18	18
Long-term outstanding power bonds, net (including current maturities)	18,889	18,866
Long-term debt of VIEs, net (including current maturities)	$ 968	$ 968

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Other Income (Expense), Net (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Other Income (Expense), Net
External services	$ 4	$ 3
Interest income	10	7
Gains (losses) on investments	9	6
Other income (expense), net	$ 23	$ 16

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Benefit Plans Components of Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Pension Plan
Retirement Plan Disclosure
Service cost	$ 7	$ 9
Interest cost	144	142
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	(124)	123
Amortization of prior service cost	(22)	(22)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	25	(34)
Net periodic benefit cost as acutarially determined	30	40
Amount capitalized due to actions of regulator	0	(19)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)	30	59
Other Postretirement Benefit Plan
Retirement Plan Disclosure
Service cost	3	3
Interest cost	5	5
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	0	0
Amortization of prior service cost	(4)	(4)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	(1)	0
Net periodic benefit cost as acutarially determined	3	4
Amount capitalized due to actions of regulator	0	0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)	3	$ 4
Defined benefit plan contributions	8
Other Pension Plan
Retirement Plan Disclosure
Defined benefit plan contributions	75
401K [Member]
Retirement Plan Disclosure
Defined benefit plan contributions	$ 35

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Benefit Plans Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Other Pension Plan
Retirement Plan Disclosure
Defined benefit plan contributions	$ 75
Pension Benefits
Retirement Plan Disclosure
Service cost	7	$ 9
Interest cost	144	142
Expected return on plan assets	124	(123)
Amortization of prior service cost	(22)	(22)
Recognized net actuarial loss	(25)	34
Total net periodic benefit cost as actuarially determined	30	40
Amount capitalized due to actions of regulator	0	19
Total net periodic benefit cost	30	59
Other Post-retirement Benefits
Retirement Plan Disclosure
Defined benefit plan contributions	8
Service cost	3	3
Interest cost	5	5
Expected return on plan assets	0	0
Amortization of prior service cost	(4)	(4)
Recognized net actuarial loss	1	0
Total net periodic benefit cost as actuarially determined	3	4
Amount capitalized due to actions of regulator	0	0
Total net periodic benefit cost	$ 3	$ 4

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Benefit Plans Contributions (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($)
Retirement Plan Disclosure
Remaining Employer Contributions	$ 225
Other Pension Plan
Retirement Plan Disclosure
Defined benefit plan contributions	75
defined benefit plan, plan assets, monthly contributions by employer	25
Other Post-retirement Benefits
Retirement Plan Disclosure
Defined benefit plan contributions	8
SERP
Retirement Plan Disclosure
Defined benefit plan contributions	6
Rebates [Member]
Retirement Plan Disclosure
Defined benefit plan contributions	1
401K [Member]
Retirement Plan Disclosure
Defined benefit plan contributions	35
Minimum | Other Pension Plan
Retirement Plan Disclosure
Defined benefit plan contributions	$ 300

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Contingencies and Legal Proceedings Contingencies (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($) Procedures Insurance_layers reactors	Sep. 30, 2023 USD ($)
Loss Contingencies
Nuclear liability insurance	$ 450
Assessment from licensees for each licensed reactor	$ 166
Number of licensed reactors in US | reactors	95
Nuclear accident assessment limitation per year per unit	$ 25
Maximum assessment per nuclear incident	1,200
Total amount of protection available	16,200
Amount of insurance available for loss at any one site	2,100
Maximum amount of retrospective premiums	114
Maximum idemnity if a covered accident takes or keeps a nuclear unit offline	490
Maximum retrospective premiums	44
Estimated future decommissioning cost	$ 7,570	$ 7,489
Number of procedures for determining estimates for the costs of nuclear decommissioning | Procedures	2
Possible additional future costs for compliance with Clean Air Act requirements	$ 228
Possible additional future costs for compliance with CCR requirements	1,600
Possible additional future costs for compliance with Clean Water requirements.	197
Estimated liability for cleanup and environmental work		16
Amount of insurance available for loss at any one site (top range)	2,800
Long-term debt of VIEs, net (including current maturities)	$ 987	927
The U.S. Congress is required to take action if these layes are exhausted | Insurance_layers	2
Environmental Remediation
Loss Contingencies
Accrual for Environmental Loss Contingencies, Significant Assumptions	26 million
Accrual for Environmental Loss Contingencies, Significant Assumptions	26 million
Nuclear
Loss Contingencies
Estimated future decommissioning cost	$ 3,847	3,808
Non-nuclear
Loss Contingencies
Estimated future decommissioning cost	$ 3,723	$ 3,681

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Contingencies and Legal Proceedings Legal Proceedings (Details)	Dec. 31, 2023 Units
Legal Proceedings
Number of licensed nuclear units	7

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Subsequent Event (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023		Dec. 31, 2022	Sep. 30, 2023
Subsequent Event [Line Items]
Redemptions and repurchases of power bonds	$ 1	[1]	$ 1
Current regulatory assets	251			$ 178
Interest expense	262		$ 262
Non-current regulatory assets	5,551			5,566
Unrealized gains/losses on commodity derivatives
Subsequent Event [Line Items]
Current regulatory assets	213			136
Non-current regulatory assets	$ 98			$ 52

[1] (1) All redemptions were at 100 percent of par.

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Gallatin Coal Combustion Residual Facilities (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Other Long-Term Liabilities
Current regulatory assets	$ 251	$ 178

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Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
State [Line Items]
Electric revenue	$ (2,732)	$ (2,959)
Off System Sales of Electricity	2
Regulated and Unregulated Operating Revenue	$ 2,765	3,015
Total long duration contract revenue recognition	2,487
Off system sales		4
Percent of wholesale Credit offered	310.00%
Percent of Generation Flexibility Credit	5.00%
Pre-commercial Ops - capitalized revenue	$ (3)	0
Regulated Operating Revenue	$ 2,731	2,963
NES's % of operating revenues	800.00%
Percent of Generation Flexibility Credit	5.00%
ALABAMA
State [Line Items]
Regulated Operating Revenue	$ 408	428
GEORGIA
State [Line Items]
Regulated Operating Revenue	69	76
KENTUCKY
State [Line Items]
Regulated Operating Revenue	177	198
MISSISSIPPI
State [Line Items]
Regulated Operating Revenue	255	278
NORTH CAROLINA
State [Line Items]
Regulated Operating Revenue	23	25
TENNESSEE
State [Line Items]
Regulated Operating Revenue	1,789	1,941
VIRGINIA
State [Line Items]
Regulated Operating Revenue	$ 11	$ 13

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Revenue Customer Type (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($) Units	Dec. 31, 2022 USD ($)
Revenue, Major Customer [Line Items]
MLGW's % of operating revenues	800.00%
NES's % of operating revenues	800.00%
Off System Sales of Electricity	$ 2
Bill credits for LTA	$ (47)	$ (48)
Number of LPCs signed LTA | Units	147
Number of LPCs signed Flexibility Agreement | Units	92
Percent of sales of electricity to LPCs	91.00%
Pre-commercial Ops - capitalized revenue	$ (3)	0
Regulated Operating Revenue	2,731	2,963
Regulated and Unregulated Operating Revenue	2,765	3,015
lpcs [Domain]
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	2,487	2,706
industries directly served [Domain]
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	217	225
federal agencies and other [Domain]
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	30	32
ALABAMA
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	408	428
GEORGIA
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	69	76
KENTUCKY
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	177	198
MISSISSIPPI
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	255	278
NORTH CAROLINA
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	23	25
TENNESSEE
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	1,789	1,941
VIRGINIA
Revenue, Major Customer [Line Items]
Regulated Operating Revenue	$ 11	$ 13

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Revenue Unpaid Incentives (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2023
Causes of Increase (Decrease) in Liability for Unpaid Claims and Claims Adjustment Expense [Line Items]
Paid Economic Incentives	$ 73	$ 82
Unpaid Economic Incentives	$ (181)		$ (188)

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Revenue Local Power Company Contracts (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($) Units
Long-term Contract for Purchase of Electric Power [Line Items]
Total long-duration contracts revenue recognition | $	2,487
Total percentage of operating revenues	90.00%
Number of LPCs signed LTA | Units	147
Total Number of LPCs | Units	153
5-year Termination Notice [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Long-Duration Contracts Revenue Recognition, Policy [Policy Text Block] | $	$ 331
Percentage of total operating revenues	12.00%
Number of LPCs signed LTA | Units	6
20-year Termination Notice [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Long-Duration Contracts Revenue Recognition, Policy [Policy Text Block] | $	$ 2,156
Percentage of total operating revenues	78.00%

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Leases (Details) - USD ($) $ in Millions	Dec. 31, 2023	Sep. 30, 2023
Amounts Recognized on TVA's Consolidated Balance Sheet [Line Items]
Finance lease, asset	$ 562	$ 572
Operating Lease, Liability, Current	81	71
Operating Lease, Liability, Noncurrent	$ 163	$ 93

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Research and Development (Details) - USD ($) $ in Millions	3 Months Ended		48 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2026
Research and Development Arrangement, Contract to Perform for Others [Line Items]
Other Research and Development Expense	$ 9	$ 16
Forecast
Research and Development Arrangement, Contract to Perform for Others [Line Items]
Other Research and Development Expense			$ 88