TENNESSEE VALLEY AUTHORITY, 10-K filed on 11/13/2025
Annual Report
v3.25.3
DEI Document
shares in Millions, $ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
shares
Document Information [Line Items]  
Entity Registrant Name TENNESSEE VALLEY AUTHORITY
Entity Central Index Key 0001376986
Entity Filer Category Non-accelerated Filer
Document Type 10-K
Document Fiscal Year Focus 2025
Document Fiscal Period Focus FY
Amendment Flag false
Entity Common Stock, Shares Outstanding | shares 0
Entity Emerging Growth Company false
Entity Shell Company false
Entity Well-known Seasoned Issuer No
Entity Public Float | $ $ 0
Document Transition Report false
Entity File Number 000-52313
Entity Tax Identification Number 62-0474417
Entity Address, State or Province TN
Entity Address, City or Town Knoxville
Entity Address, Address Line One 400 W. Summit Hill Drive
Local Phone Number 632-2101
City Area Code (865)
Entity Address, Postal Zip Code 37902 (Zip Code)
Entity Interactive Data Current Yes
ICFR Auditor Attestation Flag true
Entity Incorporation, State or Country Code X1
Entity Current Reporting Status Yes
Document Annual Report true
Document Period End Date Sep. 30, 2025
Entity Small Business false
Entity Voluntary Filers No
Current Fiscal Year End Date --09-30
Document Financial Statement Error Correction [Flag] false
Auditor Name Ernst & Young LLP
v3.25.3
Audit Information
 12 Months Ended
Sep. 30, 2025
Auditor [Line Items]  
Auditor Name Ernst & Young LLP
Auditor Location Chattanooga, Tennessee
Auditor Firm ID 42
v3.25.3
CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Operating revenues      
Regulated Operating Revenue $ 13,486 $ 12,128 $ 11,899
Revenue from sales of electricity 13,672 12,314 12,054
Operating expenses      
Fuel 2,376 2,169 2,549
Purchased power 2,106 1,581 1,633
Operating and maintenance 3,717 3,641 3,372
Depreciation and amortization 2,271 2,138 2,213
Tax equivalents 633 557 593
Total operating expenses 11,103 10,086 10,360
Operating income 2,569 2,228 1,694
Other income (expense), net 92 71 61
Defined Benefit Plan, Other Cost (Credit) 105 98 199
Interest expense      
Interest expense 1,196 1,066 1,056
Net income (loss) 1,360 1,135 500
Other Operating Segment      
Operating revenues      
Unregulated Operating Revenue $ 186 $ 186 $ 155
v3.25.3
CONSOLIDATED BALANCE SHEETS
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
Sep. 30, 2024
USD ($)
Current assets    
Cash and Cash Equivalent $ 1,576 $ 502
Accounts receivable, net 2,119 1,801
Inventories, net 1,193 1,155
Regulatory assets 127 191
Other current assets 162 120
Total current assets 5,177 3,769
Property, Plant and Equipment, Gross 71,574 70,989
Property, plant, and equipment    
Less accumulated depreciation (38,716) (38,793)
Net completed plant 32,858 32,196
Construction in progress 6,760 4,879
Nuclear fuel 1,185 1,261
Finance Lease, Right-of-Use-Asset, after Accumulated Amortization 663 729
Total property, plant, and equipment, net 41,466 39,065
Long-term Investments 5,573 4,968
Regulatory and other long-term assets    
Regulatory assets 8,047 9,408
Operating Lease, Right-of-Use Asset 113 149
Other long-term assets 506 344
Investments and Other Noncurrent Assets 8,666 9,901
Total assets 60,882 57,703
Current liabilities    
Accounts payable and accrued liabilities 3,299 2,910
Accrued interest 348 280
Asset Retirement Obligation, Current 313 283
Regulatory liabilities 228 174
Short-term debt, net of discounts 0 1,167
Total Current maturities of power bonds issued at par 1,370 1,022
Current maturities of long-term debt of variable interest entities issued at par 49 37
Total current liabilities 5,607 5,873
Other liabilities    
Post-retirement and post-employment benefit obligations 2,183 2,887
Asset retirement obligations 10,101 10,523
Finance Lease, Liability, Noncurrent 640 700
Other long-term liabilities 1,606 1,712
Non-current regulatory liabilities 141 83
Noncurrent Liabilities Other than Long-Term Debt 14,671 15,905
Long-term debt, net    
Long-term power bonds, net 20,461 17,867
Long-term debt of variable interest entities, net 1,632 897
Total long-term debt, net 22,093 18,764
Total liabilities 42,371 40,542
Proprietary capital    
Power program appropriation investment 258 258
Power program retained earnings 17,797 16,437
Total power program proprietary capital 18,055 16,695
Nonpower programs appropriation investment, net 510 518
Accumulated other comprehensive income (loss) (54) (52)
Total proprietary capital 18,511 17,161
Liabilities and Equity $ 60,882 $ 57,703
Holly Springs    
Proprietary capital    
Number of customers with allowance for uncollectible accounts | Units 1  
v3.25.3
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents $ 1,597 $ 523 $ 521
Cash flows from operating activities      
Net income (loss) 1,360 1,135 500
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) 2,293 2,160 2,235
Amortization of nuclear fuel cost 308 364 371
Non-cash retirement benefit expense 148 138 241
Amortization of Regulatory Asset 63 71 31
Changes in current assets and liabilities      
Accounts receivable, net (209) (16) 301
Inventories and other current assets, net (56) (70) (83)
Accounts payable and accrued liabilities 61 44 (1)
Accrued interest 67 8 (1)
Pension contributions (310) (304) (306)
Asset Retirement Obligation, Cash Paid to Settle (258) (283) (327)
Other, net (143) (102) (89)
Net cash provided by operating activities 3,324 3,003 2,872
Cash flows from investing activities      
Construction expenditures (4,457) (3,281) (2,526)
Nuclear fuel expenditures (224) (294) (273)
Acquisition of leasehold interests in combustion turbine assets 0 0 155
Purchases of investments (48) (52) (51)
Payments to Acquire Loans Receivable 0 4 7
Loans and other receivables      
Repayments 12 6 8
Other, net 56 34 10
Net cash used in investing activities (4,661) (3,591) (2,994)
Long-term debt      
Issues of power bonds 3,967 991 992
Redemptions and repurchases of power bonds (1,022) (1,022) (29)
Payments on debt of variable interest entities (41) (35) (39)
Short-term debt issues (redemptions), net (1,166) 734 (740)
Finance Lease, Principal Payments 82 76 56
Financing costs, net (30) (5) (4)
Other, net (15) 3 (1)
Net cash (used in) provided by financing activities 2,411 590 123
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect   2 1
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total 1,074    
Proceeds from Issuance of Debt $ 800 $ 0 $ 0
v3.25.3
CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Sep. 30, 2022
Net income (loss) $ 1,360 $ 1,135 $ 500  
Total other comprehensive income (loss) (2) (23) 57  
Return on power program appropriation investment (8) (7) (6)  
Appropriation-investment power program 258 258    
Retained Earnings Power Program 17,797 16,437    
Appropriation investment nonpower programs, net 510 518    
Accumulated other comprehensive income (loss) (54) (52) (29) $ (86)
Proprietary Capital 18,511 17,161 16,056 15,505
Power Program Appropriation Investment        
Net income (loss) 0 0 0  
Total other comprehensive income (loss) 0 0 0  
Return on power program appropriation investment 0 0 0  
Appropriation-investment power program 258 258 258 258
Power Program Retained Earnings        
Net income (loss) 1,368 1,142 508  
Total other comprehensive income (loss) 0 0 0  
Return on power program appropriation investment (8) (7) 6  
Retained Earnings Power Program 17,797 16,437 15,302 14,800
Nonpower Programs Appropriation Investment, Net        
Net income (loss) (8) (7) (8)  
Total other comprehensive income (loss) 0 0 0  
Return on power program appropriation investment 0 0 0  
Appropriation investment nonpower programs, net 510 518 525 $ 533
Accumulated Other Comprehensive Income (Loss) Net Gains (Losses) on Cash Flow Hedges        
Net income (loss) 0 0 0  
Total other comprehensive income (loss) (2) (23) 57  
Return on power program appropriation investment $ 0 $ 0 $ 0  
v3.25.3
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) Statement - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Statement of Comprehensive Income [Abstract]      
Net income (loss) $ 1,360 $ 1,135 $ 500
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, after Tax 1 25 99
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, after Tax (3) (48) (42)
Total other comprehensive income (loss) (2) (23) 57
Total comprehensive income (loss) $ 1,358 $ 1,112 $ 557
v3.25.3
Supplemental Cash Flow Information
 12 Months Ended
Sep. 30, 2025
Supplemental Cash Flow Information [Abstract]  
Supplemental Cash Flow Information Interest paid was $1.1 billion in each of 2025, 2024, and 2023. These amounts differ from interest expense in certain years due to the timing of payments. There was no interest capitalized in 2025, 2024, or 2023.
    Construction in progress and nuclear fuel expenditures included in Accounts payable and accrued liabilities at September 30, 2025, 2024, and 2023 were $1.2 billion, $898 million, and $559 million, respectively, and are excluded from the Consolidated Statements of Cash Flows for the years ended September 30, 2025, 2024, and 2023 as non-cash investing activities. ARO project accruals included in Accounts payable and accrued liabilities at September 30, 2025, 2024, and 2023 were $57 million, $45 million, and $71 million, respectively, and are excluded from the Consolidated Statements of Cash Flows for the years ended September 30, 2025, 2024, and 2023 as non-cash operating activities.

Excluded from the Consolidated Statements of Cash Flows for the year ended September 30, 2024, were non-cash investing and financing activities of $230 million primarily related to two finance leases. There was a $56 million lease asset and lease liability recorded as a result of a new finance lease entered into in May 2024. In addition, there was a $163 million lease liability and a $179 million lease asset recorded as a remeasurement of an existing lease due to change in lease term. There are no material finance leases that were entered into during the years ended September 30, 2025 and 2023. See Note 9 — Leases for further information regarding TVA's finance leases.

    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.
v3.25.3
Supplemental Cash Flow Information
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Supplemental Cash Flow Information      
Interest Paid, Excluding Capitalized Interest, Operating Activity $ 1,100 $ 1,100 $ 1,100
ARO project accruals included in AP 57 45 71
Capital Expenditures Incurred but Not yet Paid 1,200 898 559
Lease Obligation Incurred   $ 163  
Finance Leased Asset, Measurement Input   179,000,000  
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability   $ 56  
Lease assets obtained in exchange for lease obligations - finance $ 28 $ 230 $ 3
v3.25.3
Summary of Significant Accounting Policies [Text Block]
 12 Months Ended
Sep. 30, 2025
Accounting Policies [Abstract]  
Summary of Significant Accounting Policies
1.  Summary of Significant Accounting Policies

General

The Tennessee Valley Authority ("TVA") is a corporate agency and instrumentality of the United States ("U.S.") that was created in 1933 by federal legislation in response to a proposal by President Franklin D. Roosevelt.  TVA was created to, among other things, improve navigation on the Tennessee River, reduce the damage from destructive flood waters within the Tennessee River system and downstream on the lower Ohio and Mississippi Rivers, further the economic development of TVA's service area in the southeastern U.S., and sell the electricity generated at the facilities TVA operates. Today, TVA operates the nation's largest public power system and supplies power in most of Tennessee, northern Alabama, northeastern Mississippi, and southwestern Kentucky and in portions of northern Georgia, western North Carolina, and southwestern Virginia to a population of approximately 10 million people.

    TVA also manages the Tennessee River, its tributaries, and certain shorelines to provide, among other things, year-round navigation, flood damage reduction, and affordable and reliable electricity. Consistent with these primary purposes, TVA also manages the river system and public lands to provide recreational opportunities, adequate water supply, improved water quality, cultural and natural resource protection, and economic development. TVA performs these management duties in cooperation with other federal and state agencies that have jurisdiction and authority over certain aspects of the river system. In addition, the TVA Board of Directors ("TVA Board") has established two councils — the Regional Resource Stewardship Council and the Regional Energy Resource Council — to advise TVA on its stewardship activities in the Tennessee Valley and its energy resource activities.

The power program has historically been separate and distinct from the stewardship programs.  It is required to be self-supporting from power revenues and proceeds from power financings, such as proceeds from the issuance of bonds, notes, or other evidences of indebtedness (collectively, "Bonds").  Although TVA does not currently receive Congressional appropriations, it is required to make annual payments to the United States Department of the Treasury ("U.S. Treasury") as a return on the government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment").  In the 1998
Energy and Water Development Appropriations Act, Congress directed TVA to fund essential stewardship activities related to its management of the Tennessee River system and nonpower or stewardship properties with power revenues in the event that there were insufficient appropriations or other available funds to pay for such activities in any fiscal year.  Congress has not provided any appropriations to TVA to fund such activities since 1999.  Consequently, during 2000, TVA began paying for essential stewardship activities primarily with power revenues, with the remainder funded with user fees and other forms of revenues derived in connection with those activities.  The activities related to stewardship properties do not meet the criteria of an operating segment under accounting principles generally accepted in the United States of America ("GAAP").  Accordingly, these assets and properties are included as part of the power program, TVA's only operating segment.

Power rates are established by the TVA Board as authorized by the Tennessee Valley Authority Act of 1933, as amended ("TVA Act").  The TVA Act requires TVA to charge rates for power that will produce gross revenues sufficient to provide funds for operation, maintenance, and administration of its power system; payments to states and counties in lieu of taxes ("tax equivalents"); debt service on outstanding indebtedness; payments to the U.S. Treasury in repayment of and as a return on the Power Program Appropriation Investment; and such additional margin as the TVA Board may consider desirable for investment in power system assets, retirement of outstanding Bonds in advance of maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected with TVA's power business.  TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment with the 2014 payment; therefore, this repayment obligation is no longer a component of rate setting. In setting TVA's rates, the TVA Board is charged by the TVA Act to have due regard for the primary objectives of the TVA Act, including the objective that power shall be sold at rates as low as are feasible.  Rates set by the TVA Board are not subject to review or approval by any state or other federal regulatory body.

Fiscal Year

TVA's fiscal year ends September 30.  Years (2025, 2024, etc.) refer to TVA's fiscal years unless they are preceded by "CY," in which case the references are to calendar years.

Cost-Based Regulation

Since the TVA Board is authorized by the TVA Act to set rates for power sold to its customers, TVA is self-regulated. Additionally, TVA's regulated rates are designed to recover its costs.  Based on current projections, TVA believes that rates, set at levels that will recover TVA's costs, can be charged and collected.  As a result of these factors, TVA records certain assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for non-regulated entities.   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.  TVA assesses whether the regulatory assets are probable of future recovery by considering factors such as applicable regulatory changes, potential legislation, and changes in technology.  Based on these assessments, TVA believes the existing regulatory assets are probable of recovery.  This determination reflects the current regulatory and political environment and is subject to change in the future.  If future recovery of regulatory assets ceases to be probable, or TVA is no longer considered to be a regulated entity, then costs would be required to be written off.  All regulatory asset write offs would be required to be recognized in earnings in the period in which future recovery ceases to be probable or in which TVA is no longer considered to be a regulated entity.

Basis of Presentation

    The accompanying consolidated 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 12 — Variable Interest Entities. Intercompany balances and transactions have been eliminated in consolidation.

Use of 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 consolidated financial statements.  Although the consolidated financial statements are prepared in conformity with GAAP, 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 considered 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.

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. See Note 23 — Commitments and Contingencies — Legal Proceedings — Environmental Agreements.

    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
At September 30
(in millions)
 20252024
Cash and cash equivalents$1,576 $502 
Restricted cash and cash equivalents included in Other long-term assets21 21 
Total cash, cash equivalents, and restricted cash$1,597 $523 

TVA's balance of Cash and cash equivalents increased at September 30, 2025 due to the issuance of long-term bonds in the fourth quarter in anticipation of cash needed to pay bond maturities in November 2025.

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/or 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. As of September 30, 2025, TVA adopted the practical expedient in accordance with the accounting guidance for Current Expected Credit Losses, to assume that the current conditions as of the balance sheet date will remain unchanged for the remaining life of the asset when developing a reasonable and supportable forecast as part of estimating expected credit losses for trade receivables based on TVA's corporate credit department assessment of the financial condition of customers and the credit quality of the receivables.

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 $14 million and less than $1 million at September 30, 2025, and 2024, respectively, for trade accounts receivable.  At September 30, 2025, the allowance for uncollectible accounts included $14 million related to one local power company customer ("LPC"). Additionally, loans receivable of $86 million and $105 million at September 30, 2025 and 2024, respectively, are included in Accounts receivable, net and Other long-term assets for the current and long-term portions, respectively. Loans receivable are reported net of allowances for uncollectible accounts of $2 million at both September 30, 2025 and 2024.

Revenues

TVA recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount to which the entity expects to be entitled in exchange for those goods or services. For the generation and transmission of electricity, this is generally at the time the power is delivered to a metered customer delivery point for the customer's consumption or distribution. As a result, revenues from power sales are recorded as electricity is delivered to customers. In addition to power sales invoiced and recorded during the month, TVA accrues estimated unbilled revenues for power sales provided to five customers whose billing date occurs prior to the end of the month.  Exchange power sales are presented in the accompanying Consolidated Statements of Operations as a component of sales of electricity. Exchange power sales are sales of excess power after meeting TVA native load and directly served requirements.  Native load refers to the customers on whose behalf a company, by statute, franchise, regulatory requirement, or contract, has undertaken an obligation to serve. TVA
engages in other arrangements in addition to power sales. Certain other revenue from activities related to TVA's overall mission is recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income, net.

Inventories

Certain Fuel, Materials, and Supplies.  Materials and supplies inventories are valued using an average unit cost method. A new average cost is computed after each inventory purchase transaction, and inventory issuances are priced at the latest moving weighted average unit cost. Coal, fuel oil, and natural gas inventories are valued using an average cost method. A new weighted average cost is computed monthly, and monthly issues are priced accordingly.

Renewable Energy Certificates. TVA accounts for Renewable Energy Certificates ("RECs") using the specific identification cost method. RECs that are acquired through power purchases are recorded as inventory and charged to purchased power expense when the RECs are subsequently used or sold. TVA assigns a value to the RECs at the inception of the power purchase arrangement using a relative standalone selling price approach. RECs created through TVA-owned asset generation are recorded at zero cost.

Emission Allowances.  TVA accounts for emission allowances using the specific identification cost method. Allowances that are acquired through third party purchases are recorded as inventory at cost and charged to operating expense based on tons emitted during the respective compliance periods.  

Allowance for Inventory Obsolescence.  TVA reviews materials and supplies inventories by category and usage on a periodic basis.  Each category is assigned a probability of becoming obsolete based on the type of material and historical usage data.  TVA has a fleet-wide inventory management policy for each generation type. Based on the estimated value of the inventory, TVA adjusts its allowance for inventory obsolescence.

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 ("CT") 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 year ended September 30, 2024. TVA also capitalized related fuel costs for this project of $3 million for the year ended September 30, 2024. Pre-commercial plant operations began on Johnsonville Aeroderivative CT Units 21-30 during 2025. Units 21-25 and 27-30 became operational on May 6, 2025, and Unit 26 became operational on August 20, 2025. Estimated revenue of $4 million related to this project was capitalized to offset project costs for the year ended September 30, 2025. TVA also capitalized related fuel costs for this project of $7 million for the year ended September 30, 2025.

Property, Plant, and Equipment, and Depreciation

    Property, Plant, and Equipment. Additions to plant are recorded at cost, which includes direct and indirect costs.  The cost of current repairs and minor replacements is charged to operating expense. When property, plant, and equipment is retired, accumulated depreciation is charged for the original cost of the assets. Gains or losses are only recognized upon the sale of land or an entire operating unit. TVA capitalizes certain costs incurred in connection with developing or obtaining internal-use software. Capitalized software costs are included in Property, plant, and equipment on the Consolidated Balance Sheets and are generally amortized over seven years.  

Nuclear Fuel. Nuclear fuel, which is included in Property, plant, and equipment, is valued using the average cost method for raw materials and the specific identification method for nuclear fuel in a reactor.  Amortization of nuclear fuel in a reactor is calculated on a units-of-production basis and is included in fuel expense.

TVA and the Department of Energy ("DOE") are parties to an interagency agreement (referred to as the Down-blend Offering for Tritium), under which surplus DOE highly enriched uranium and other uranium is processed by third-party contractors into low-enriched uranium, which is then fabricated into nuclear fuel for use in TVA's nuclear power plants.  Production of the low-enriched uranium began in 2019 and will continue through the end of the interagency agreement term in September 2027. After that date, any remaining uranium in storage will be managed to ensure that the uranium is unencumbered by policy restrictions, so that it can be used in connection with the production of tritium. Under the terms of the interagency agreement, the DOE will reimburse TVA for a portion of the costs of converting the highly enriched uranium to low-enriched uranium. Since 2019, TVA has received $334 million in reimbursements from the DOE, which is recorded as a reduction in nuclear fuel inventory costs. At September 30, 2025, TVA recorded $6 million in Accounts receivable, net related to this agreement.

    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 in 2022.

Depreciation expense for the years ended September 30, 2025, 2024, and 2023 was $1.9 billion, $1.8 billion, and $1.9 billion, respectively. Depreciation expense expressed as a percentage of the average annual depreciable completed plant was 3.04 percent for 2025, 2.92 percent for 2024, and 3.14 percent for 2023.  Average depreciation rates by asset class are as follows:
Property, Plant, and Equipment Depreciation Rates
At September 30
(percent)
202520242023
Asset Class
Nuclear2.71 2.71 2.73 
Coal-fired(1)
4.82 4.13 4.98 
Hydroelectric1.82 1.83 1.82 
Gas and oil-fired3.16 3.31 3.17 
Transmission1.55 1.52 1.52 
Other5.22 4.98 4.43 
Note
(1) The rates include the acceleration of depreciation related to retiring certain coal-fired units and potentially retiring the remainder of the coal-fired fleet by 2035. See Note 8 — Plant Closures.

Reacquired Rights. TVA previously entered into leasing transactions to obtain third-party financing for 24 peaking CTs as well as certain qualified technological equipment and software. All of the lease proceeds were accounted for as financing obligations due to TVA’s continuing involvement with the combustion turbine facilities and the qualified technological equipment and software during the leaseback term. These financial obligations were paid off, and TVA acquired the residual leasehold interests for all of this equipment and recorded the cash consideration as reacquired rights, which is an intangible asset included in property, plant, and equipment on the Consolidated Balance Sheet. At September 30, 2025 and 2024, property, plant, and equipment includes intangible reacquired rights, net of amortization, of $301 million and $312 million, respectively. Reacquired rights are amortized over the estimated useful lives of the underlying CTs which range from 30 to 35 years. Amortization expense was $11 million, $11 million, and $10 million for the years ended September 30, 2025, 2024, and 2023, respectively, and accumulated amortization at September 30, 2025 and 2024 totaled $74 million and $63 million, respectively. At September 30, 2025, the estimated aggregate amortization expense for each of the next five years and thereafter is shown below:

 20262027202820292030Thereafter
Reacquired Rights$11 $12 $11 $11 $12 $244 

Impairment of Assets.  TVA evaluates long-lived assets for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.  For long-lived assets, TVA bases its evaluation on impairment indicators such as the nature of the assets, the future economic benefit of the assets, any historical or future profitability measurements, regulatory approval and ability to set rates at levels that allow for recoverability of the assets, and other external market conditions or factors that may be present.  If such impairment indicators are present or other factors exist that indicate that the carrying amount of an asset may not be recoverable, TVA determines whether an impairment has occurred based on an estimate of undiscounted cash flows attributable to the asset as compared with the carrying value of the asset.  If an impairment has occurred, the amount of the impairment recognized is measured as the excess of the asset's carrying value over its fair value.  Additionally, TVA regularly evaluates construction projects.  If the project is canceled or deemed to have no future economic benefit, the project is written off as an asset impairment or, upon TVA Board approval, reclassified as a regulatory asset and amortized over the Board-approved period. See Note 8 — Plant Closures.

Leases

    TVA recognizes a lease asset and lease liability for leases with terms of greater than 12 months. Lease assets represent TVA's right to use an underlying asset for the lease term, and lease liabilities represent TVA's obligation to make lease payments arising from the lease, both of which are recognized based on the present value of the future minimum lease payments over the lease term at the commencement date.  TVA has certain lease agreements that include variable lease payments that are based on energy production levels. These variable lease payments are not included in the measurement of the lease assets or lease liabilities but are recognized in the period in which the expenses are incurred.

    While not specifically structured as leases, certain power purchase agreements ("PPAs") are deemed to contain a lease of the underlying generating units when the terms convey the right to control the use of the assets. Amounts recorded for these leases are generally based on the amount of the scheduled capacity payments due over the remaining terms of the PPAs, the
terms of which vary. The total lease obligations included in Accounts payable and accrued liabilities, Other long-term liabilities, and Finance lease liabilities related to these agreements were $509 million and $75 million for finance and operating leases, respectively, at September 30, 2025. The total lease obligations included in Accounts payable and accrued liabilities, Other long-term liabilities, and Finance lease liabilities related to these agreements were $550 million and $121 million for finance and operating leases, respectively, at September 30, 2024.

    TVA has agreements with lease and non-lease components and has elected to separate lease and non-lease components. Consideration is allocated to lease and non-lease components generally based on relative standalone price basis. Variable lease costs included in the agreements are allocated based on the determination of lease and non-lease components.

    TVA has lease agreements which include options for renewal and early termination. The intent to renew a lease varies depending on the lease type and asset. Renewal options that are reasonably certain to be exercised are included in the lease measurements. The decision to terminate a lease early is dependent on various economic factors. No termination options have been included in TVA's lease measurements.
    
    Leases with an initial term of 12 months or less, which do not include an option to extend the initial term of the lease to greater than 12 months that TVA is reasonably certain to exercise, are not recorded on the Consolidated Balance Sheets at September 30, 2025.
    Operating leases are recognized on a straight-line basis over the term of the lease agreement. Rent expense associated with short-term leases and variable leases is recorded in Operating and maintenance expense, Fuel expense, or Purchased power expense on the Consolidated Statements of Operations. Expenses associated with finance leases result in the separate presentation of interest expense on the lease liability and amortization expense of the related lease asset on the Consolidated Statements of Operations.

Decommissioning Costs

    TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets.  These obligations relate to fossil fuel-fired generating plants, nuclear generating plants, hydroelectric generating plants/dams, transmission structures, and other property-related assets.  Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site restoration. Revisions to the forecasted costs of decommissioning activities are made whenever factors indicate that the timing or amounts of estimated cash flows have changed materially. Studies are updated for both nuclear and non-nuclear decommissioning costs at least every five years.  Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset.  See Note 11 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs and Note 14 — Asset Retirement Obligations.

Investment Funds

    Investment funds consist primarily of trust funds designated to fund decommissioning requirements (see Note 23 — Commitments and Contingencies — Contingencies — Decommissioning Costs), the Supplemental Executive Retirement Plan ("SERP") (see Note 21 — Benefit Plans — Overview of Plans and Benefits — Supplemental Executive Retirement Plan), the Deferred Compensation Plan ("DCP"), and the Restoration Plan ("RP"). The Nuclear Decommissioning Trust ("NDT") holds funds primarily for the ultimate decommissioning of TVA's nuclear power plants. The Asset Retirement Trust ("ART") holds funds primarily for the costs related to the future closure and retirement of TVA's other long-lived assets. 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 funds are all classified as trading.

Research and Development Costs

Research and development costs are expensed when incurred.  TVA's research programs include those related to power delivery technologies, emerging technologies, technologies related to generation (fossil fuel, nuclear, and hydroelectric), and environmental technologies.

Tax Equivalents

TVA is not subject to federal income taxation. In addition, neither TVA nor its property, franchises, or income is subject to taxation by states or their subdivisions. The TVA Act requires TVA to make payments to states and counties in which TVA conducts its power operations and in which TVA has acquired power properties previously subject to state and local taxation.   The total amount of these payments is five percent of gross revenues from sales of power during the preceding year, excluding sales or deliveries to other federal agencies and off-system sales with other utilities, with a provision for minimum payments under certain circumstances. TVA calculates tax equivalent expense by subtracting the prior year fuel cost-related tax equivalent regulatory asset or liability from the payments made to the states and counties during the current year and adding back the current year fuel cost-related tax equivalent regulatory asset or liability. Fuel cost-related tax equivalent expense is recognized in the same accounting period in which the fuel cost-related revenue is recognized.
Maintenance Costs
TVA records maintenance costs and repairs related to its property, plant, and equipment on the Consolidated Statements of Operations as they are incurred except for the recording of certain regulatory assets for retirement and removal costs.
v3.25.3
Impact of New Accounting Standards and Interpretations
 12 Months Ended
Sep. 30, 2025
Accounting Changes and Error Corrections [Abstract]  
Accounting Standards Update and Change in Accounting Principle [Text Block] Impact of New Accounting Standards and Interpretations
The following are accounting standard updates issued by the Financial Accounting Standards Board ("FASB") that TVA adopted during 2025:
Improvements to Reportable Segment Disclosures
DescriptionThis guidance improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The amendments require a public entity to disclose, on an annual and interim basis, significant segment expenses that are regularly provided to the Chief Operating Decision Maker ("CODM") 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 amendments and all existing segment disclosures. The amendments are effective for public entities for fiscal years beginning after December 15, 2023, and interim periods in fiscal years beginning after December 15, 2024. Upon adoption, a public entity should apply the amendments retrospectively to all prior periods presented in the financial statements.
Effective Date for TVATVA adopted the guidance on September 30, 2025, and applied it retrospectively.
Effect on the Financial Statements or Other Significant Matters
The adoption of this standard resulted in expanded disclosures of significant segment expenses and enhanced qualitative information about the CODM's title and the use of net income as the segment profit measure. See Note 25 — Segment Reporting for further details.
Measurement of Credit Losses for Accounts Receivable and Contract Assets
DescriptionThe amended guidance simplifies the estimation of credit losses on current accounts receivable and current contract assets arising from transactions accounted for under the accounting guidance for Revenue from Contracts with Customers. The amendments allow all entities to elect a practical expedient to assume that the current conditions as of the balance sheet date will remain unchanged for the remaining life of the asset when developing a reasonable and supportable forecast as part of estimating expected credit losses on these assets.
Effective Date for TVA
This new standard is effective for TVA’s interim and annual reporting periods beginning October 1, 2026. Early adoption is permitted, and TVA adopted this standard on September 30, 2025, on a prospective basis.
Effect on the Financial Statements or Other Significant MattersAdoption of this standard did not have a material impact on TVA’s financial condition, results of operations, or cash flows.
The following accounting standards or rules have been issued but as of September 30, 2025, were not effective and had not been adopted by TVA:
Enhancement and Standardization of Climate-Related Disclosures for Investors
DescriptionIn March 2024, the Securities and Exchange Commission ("SEC") adopted its climate-related final rule (SEC Release No. 34-99678, The Enhancement and Standardization of Climate-Related Disclosures for Investors). In April 2024, the SEC voluntarily stayed the new rule as a result of pending legal challenges, in March 2025, the SEC withdrew its legal defense of the rule, and in April 2025, the United States Court of Appeals for the Eighth Circuit suspended the litigation over the validity of the rule. The new rule, if implemented as adopted, will require registrants to provide certain climate-related information in their annual reports and registration statements and will also require the dollar impact of severe weather events and other natural conditions, as well as amounts related to carbon offsets and renewable energy credits or certificates, to be disclosed in the audited financial statements in certain circumstances. If the new rule is implemented as adopted, the disclosure requirements will begin phasing in for fiscal years beginning on or after January 1, 2027 for non-accelerated filers.
Effective Date for TVA
Fiscal year beginning October 1, 2027.
Effect on the Financial Statements or Other Significant MattersTVA is currently evaluating the impact of the rule on its disclosures.
Disaggregation of Income Statement Expenses
DescriptionThis guidance improves the disclosures about a public entity's expenses in the notes to the financial statements and requires disclosure of specified information about certain costs and expenses. The amendments require a public entity to disclose, on an annual and interim basis, purchases of inventory, employee compensation, depreciation, intangible asset amortization, and depletion for each income statement line item that contains those expenses. Specified expenses, gains, or losses that are already disclosed under existing U.S. GAAP are required to be included in the disaggregated income statement expense line item disclosures, and any relevant remaining amounts need to be described qualitatively. Separate disclosures of total selling expenses and an entity’s definition of those expenses are also required. The amendments are effective for public entities for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027. Upon adoption, a public entity can apply the amendments prospectively or apply them retrospectively to all prior periods presented in the financial statements.
Effective Date for TVAFiscal year beginning October 1, 2027, and interim periods beginning October 1, 2028.
Effect on the Financial Statements or Other Significant MattersThe adoption of this standard will result in TVA including the additional required disclosures, and TVA does not expect an impact on its financial condition, results of operations, or cash flows.

Accounting and Disclosure of Costs Related to Internally Developed Software
DescriptionThis guidance amends the accounting for and disclosure of costs related to internally developed software, eliminating project stages, clarifying significant development uncertainty by requiring costs to be recognized only when uncertainty is resolved, and aligning capitalization rules with those for externally sold software. Key changes include the elimination of distinct project stages for development, a redefined meaning of probable as likely, and requirements to assess significant development uncertainty for all software projects to determine when to capitalize costs. In addition, the guidance specifies that the property, plant, and equipment disclosure requirements shall be applied to all capitalized software costs. The amendments are effective for all public entities for fiscal years beginning after December 15, 2027, and interim periods within those fiscal years. Upon adoption, a public entity may apply the guidance using a prospective, retrospective, or modified transition approach.
Effective Date for TVAThe new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2028.
Effect on the Financial Statements or Other Significant MattersThe adoption of this standard is not expected to have a material impact on TVA’s financial condition, results of operations, cash flows, or disclosures.
v3.25.3
Accounts Receivable, Net
 12 Months Ended
Sep. 30, 2025
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
At September 30
(in millions)
 20252024
Power receivables$1,908 $1,683 
Other receivables225 118 
Allowance for uncollectible accounts(1) (2)
(14)— 
Accounts receivable, net$2,119 $1,801 
Note
(1) 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, among other considerations. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts. At September 30, 2025, the allowance for uncollectible accounts included $14 million related to one LPC customer.
(2) The allowance for uncollectible accounts was less than $1 million at September 30, 2024.
In addition, the Inflation Reduction Act of 2022 ("IRA") makes credits available to certain tax-exempt entities, including TVA. Obtaining this funding requires TVA to meet certain requirements, to submit informational returns to the Internal Revenue Service ("IRS"), and to retain adequate books and records to support its filings. TVA records the credit when there is reasonable assurance that the credit will be received, and TVA complies with all conditions attached to the eligibility of the credit. The credit is recognized as a reduction of the asset and/or expense based on what the credits are intended to reimburse. At September 30, 2025, TVA recorded $72 million in Accounts receivable, net, which is classified as Other receivables above, related to these tax credits; $51 million was recorded as a reduction of Net completed plant; $19 million was recorded to reduce Operating and maintenance expense; and $2 million related to interest was recorded to Other income, net. There were no tax credits recorded in 2024. TVA received $26 million in October 2025 related to these credits.
v3.25.3
Inventories, Net
 12 Months Ended
Sep. 30, 2025
Inventory, Net [Abstract]  
Inventories, Net .  Inventories, Net
The table below summarizes the types and amounts of TVA's inventories:
Inventories, Net 
At September 30
(in millions)
 20252024
Materials and supplies inventory$986 $931 
Fuel inventory278 286 
Renewable energy certificates/emissions allowance inventory, net12 11 
Allowance for inventory obsolescence(83)(73)
Inventories, net$1,193 $1,155 
v3.25.3
Deferred Costs, Capitalized, Prepaid, and Other Assets - Text Block
 12 Months Ended
Sep. 30, 2025
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]  
Other Current Assets
6. Other Current Assets

Other current assets consisted of the following:
Other Current Assets 
At September 30
(in millions)
 2025
2024(1)
Inventory work-in-progress$69 $41 
Prepaid software maintenance25 22 
Prepaid insurance16 19 
Current portion of prepaid long-term service agreements16 7 
Commodity contract derivative assets14 5 
Prepaid dues & fees7 6 
Cloud assets3 13 
Other12 7 
Other current assets$162 $120 
Note
(1) At September 30, 2024, $6 million previously classified as Other (a component of Other current assets) has been reclassified to Prepaid dues & fees (a component of Other current assets) to conform to current year presentation.

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 16 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Contract Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.
v3.25.3
Net Completed Plant
 12 Months Ended
Sep. 30, 2025
Property, Plant and Equipment, Net, by Type [Abstract]  
Property, Plant, and Equipment and Intangible Assets . Net Completed Plant
Net completed plant consisted of the following:
Net Completed Plant
At September 30
(in millions)
 20252024
 CostAccumulated Depreciation 
Net		CostAccumulated DepreciationNet
Nuclear$27,091 $14,682 $12,409 $26,800 $14,149 $12,651 
Coal-fired(1)
19,029 15,760 3,269 20,177 16,635 3,542 
Gas, oil-fired, and other production7,746 2,274 5,472 7,051 2,112 4,939 
Transmission10,323 3,542 6,781 9,964 3,450 6,514 
Hydroelectric4,391 1,352 3,039 4,307 1,288 3,019 
Other electrical plant2,068 678 1,390 1,763 737 1,026 
Multipurpose dams900 419 481 900 413 487 
Other stewardship26 9 17 27 9 18 
Total$71,574 $38,716 $32,858 $70,989 $38,793 $32,196 
Note
(1) TVA recognized accelerated depreciation as a result of the decision to idle or retire certain units and the potential retirement of the remainder of the coal-fired fleet by 2035. See Note 8 — Plant Closures.
v3.25.3
Other Long-Term Assets [Text Block]
 12 Months Ended
Sep. 30, 2025
Assets, Noncurrent [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 
At September 30
(in millions)
 20252024
Cloud assets$114 $35 
Prepaid long-term service agreements89 62 
Loans and other long-term receivables, net83 84 
Prepaid capital assets81 29 
EnergyRight® receivables, net
45 44 
Commodity contract derivative assets10 2 
Other84 88 
Total other long-term assets$506 $344 

Cloud Assets. TVA has capitalized the implementation costs of hosting arrangements that are considered service contracts as cloud assets. The cloud assets are amortized over the non-cancellable terms of the hosting arrangement, including renewal periods that are reasonably certain to be exercised. The current and long-term portions of the cloud assets are reported in Other current assets and Other long-term assets, respectively, on TVA’s Consolidated Balance Sheets. Amortization of the cloud asset is recognized in Operating and maintenance expense, consistent with the classification of the related hosting fees. At September 30, 2025, and September 30, 2024, the carrying amount of the cloud assets reported in Other current assets was $3 million and $13 million, respectively. For the years ended September 30, 2025, 2024, and 2023, TVA amortized $14 million, $15 million, and $7 million, respectively, as Operating and maintenance expense.

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 September 30, 2025 and 2024, prepayments of $16 million and $7 million, respectively, were recorded in Other current assets.

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 September 30, 2025 and 2024, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $3 million and $21 million, respectively. Loans receivables are reported net of allowances for uncollectible accounts. 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
At September 30
(in millions)
20252024
EnergyRight® loan reserve
$1 $1 
Economic development loan specific loan reserve1 1 
Total allowance for loan losses$2 $2 

Prepaid Capital Assets. TVA makes prepayments to acquire capital assets. TVA classifies these prepayments as prepaid capital if the funds are refundable, and TVA can receive a credit.

EnergyRight® Receivables. In association with the EnergyRight® program, TVA's 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 both September 30, 2025 and 2024, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $12 million. See Note 13 — Other Long-Term Liabilities for information regarding the associated financing obligation.
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 16 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Contract Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.
v3.25.3
Regulatory Assets and Liabilities [Text Block]
 12 Months Ended
Sep. 30, 2025
Regulatory Assets and Liabilities Disclosure [Abstract]  
Regulatory Assets and Liabilities .  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 
At September 30
(in millions)
 20252024
Current regulatory assets 
Unrealized losses on commodity contract derivatives$59 $102 
Unrealized losses on interest rate derivatives57 54 
Fuel cost adjustment receivable— 35 
Other current regulatory assets11 — 
Total current regulatory assets127 191 
Non-current regulatory assets  
Non-nuclear decommissioning costs5,563 6,187 
Retirement benefit plans deferred costs1,531 1,979 
Unrealized losses on interest rate derivatives316 447 
Environmental compliance and remediation costs308 215 
Nuclear decommissioning costs149 362 
Unrealized losses on commodity contract derivatives12 64 
Other non-current regulatory assets168 154 
Total non-current regulatory assets8,047 9,408 
Total regulatory assets$8,174 $9,599 
Current regulatory liabilities  
Fuel cost adjustment tax equivalents$203 $169 
Unrealized gains on commodity contract derivatives14 5 
Fuel cost adjustment payable11 — 
Total current regulatory liabilities228 174 
Non-current regulatory liabilities  
Retirement benefit plans deferred credits131 81 
Unrealized gains on commodity contract derivatives10 2 
Total non-current regulatory liabilities141 83 
Total regulatory liabilities$369 $257 

Unrealized Gains (Losses) on Commodity Contract Derivatives.  TVA enters into certain commodity contract derivatives for natural gas that require the physical delivery of the contracted quantity. Unrealized gains (losses) on natural gas purchase contracts, included as part of unrealized gains (losses) on commodity contract derivatives, relate to the mark-to-market ("MtM") valuation of natural gas purchase contracts.  The natural gas purchase contracts qualify as commodity contract derivatives but do not qualify for cash flow hedge accounting treatment.  As a result, TVA recognizes the changes in the market value of these commodity contract derivatives as a regulatory liability or asset.  This treatment reflects TVA's ability and intent to recover the cost of these commodity contract derivatives on a settlement basis for ratemaking purposes through the fuel cost adjustment. TVA recognizes the actual cost of fuel received under these contracts in fuel and purchased power expense at the time the fuel is used to generate electricity.  These contracts expire at various times through October 2035.  Unrealized gains and losses on
contracts with a maturity of less than one year are included as a current regulatory asset or liability on TVA's Consolidated Balance Sheets.  See Note 16 — Risk Management Activities and Derivative Transactions.

Currently, TVA is hedging exposure to the price of natural gas under the Financial Hedging Program ("FHP"). Deferred gains and losses relating to TVA's FHP are included as part of unrealized gains and losses on commodity contract derivatives. TVA defers all MtM unrealized gains or losses as regulatory liabilities or assets, respectively, and records the realized gains or losses in fuel and purchased power expense as the contracts settle to match the delivery period of the underlying commodity. These contracts expire at various times through December 2029. This accounting treatment reflects TVA's ability and intent to include the realized gains or losses of these commodity contract derivatives in future periods through the fuel cost adjustment. Net unrealized gains and losses for any settlements that occur within 12 months or less are classified as a current regulatory liability or asset on TVA's Consolidated Balance Sheets. See Note 16 — Risk Management Activities and Derivative Transactions.

Unrealized Losses on Interest Rate Derivatives.  TVA uses regulatory accounting treatment to defer the unrealized gains and losses on certain interest rate derivative contracts. When amounts in these contracts are realized, the resulting gains or losses are included in the ratemaking formula.  The unrealized losses on these interest rate derivatives are recorded on TVA's Consolidated Balance Sheets as current and non-current regulatory assets, and the related realized gains or losses, if any, are recorded on TVA's Consolidated Statements of Operations when the contracts settle. A portion of certain unrealized gains and losses will be amortized into earnings over the remaining lives of the contracts. Gains and losses on interest rate derivatives that are expected to be realized within the next year are included as a current regulatory asset or liability on TVA's Consolidated Balance Sheets.

TVA does not recognize unrealized gains and losses from the investment portfolios and derivative instruments within earnings but rather defers all such gains and losses within a regulatory liability or asset in accordance with its accounting policy. See Note 16 — Risk Management Activities and Derivative Transactions and Note 17 — Fair Value Measurements.

Fuel Cost Adjustment.  The fuel cost adjustment provides a mechanism to alter rates monthly to reflect changing fuel and purchased power costs. There is typically a lag between the occurrence of a change in fuel and purchased power costs and the reflection of the change in fuel rates.  Balances in the fuel cost adjustment regulatory accounts represent over-collected or under-collected revenues that offset fuel and purchased power costs, and the fuel rate is designed to recover or refund the balance in less than one year.

Non-Nuclear Decommissioning Costs.  Non-nuclear decommissioning costs include (1) certain deferred charges related to the future closure and decommissioning of TVA's non-nuclear long-lived assets, (2) recognition of changes in the liability, (3) recognition of changes in the value of TVA's ART, and (4) certain other deferred charges under the accounting rules for asset retirement obligations ("AROs").  TVA has established the ART to more effectively segregate, manage, and invest funds to help meet future non-nuclear AROs.  The funds from the ART may be used, among other things, to pay the costs related to the future closure and retirement of non-nuclear long-lived assets under various legal requirements.  These future costs can be funded through a combination of investment funds set aside in the ART, future earnings on those investment funds, and future cash contributions to the ART.  TVA recovers in rates an amount determined by the average life of debt financed for non-nuclear decommissioning expenditures, assuming a 20-year debt service period, and contributions to the ART. Deferred charges will be recovered in rates based on an analysis of the expected expenditures, contributions, and investment earnings required to recover the decommissioning costs. Recovery of future decommissioning costs is dependent upon the future earnings of the ART, timing of decommissioning activities, and changes in decommissioning estimates. The regulatory asset is classified as long-term as amounts recovered are used to service debt or to contribute to the ART, which is restricted for future decommissioning costs.

Retirement Benefit Plans Deferred Costs (Credits).  TVA measures the funded status of its pension and post-retirement ("OPEB") benefit plans at each year-end balance sheet date. The funded status is measured as the difference between the fair value of plan assets and the benefit obligations at the measurement date for each plan. The changes in funded status are actuarial gains and losses that are recognized on TVA's Consolidated Balance Sheets by adjusting the recognized pension and OPEB liabilities, with the offset deferred as a regulatory asset or a regulatory liability. In an unregulated environment, these deferred costs (credits) would be recognized as an increase or decrease to accumulated other comprehensive income (loss) ("AOCI").

    "Incurred cost" is a cost arising from cash paid out or an obligation to pay for an acquired asset or service, and a loss from any cause that has been sustained and for which payment has been or must be made. In the cases of pension and OPEB costs, the unfunded obligation represents a projected liability to the employee for services rendered, and thus it meets the definition of an incurred cost. Therefore, amounts that otherwise would be charged to AOCI for these costs are recorded as a regulatory asset or liability since TVA has historically recovered pension and OPEB expense in rates. Through historical and current year expense included in ratemaking, the TVA Board has demonstrated the ability and intent to include pension and OPEB costs in allowable costs and in rates for ratemaking purposes. As a result, it is probable that future revenue will result from inclusion of the pension and OPEB regulatory assets or regulatory liability in allowable costs for ratemaking purposes.
    The regulatory asset and liability are classified as long-term, which is consistent with the pension and OPEB liabilities, and are not amortized to the Consolidated Statements of Operations over a specified recovery period. They are adjusted either upward or downward each year in conjunction with the adjustments to the unfunded pension liability and OPEB liability, as calculated by the actuaries. Ultimately the regulatory asset and liability will be recognized in the Consolidated Statements of Operations in the form of pension and OPEB expense as the actuarial liabilities are eliminated in future periods. See Note 21 — Benefit Plans — Obligations and Funded Status.

    Additionally on October 1, 2014, TVA began recognizing pension costs as a regulatory asset to the extent that the amount calculated under GAAP as pension expense differs from the amount TVA contributes to the pension plan. As a result of previous plan design changes, future contributions are expected to exceed the expense calculated under U.S. GAAP. Accordingly, TVA discontinued this regulatory accounting practice as all such deferred costs were recovered as of September 30, 2023.

Environmental Compliance and Remediation Costs. TVA uses regulatory accounting for certain amounts associated with compliance with an order, regulation, settlement, or lawsuit, or certain costs associated with environmental remediation activities, including but not limited to those involving environmental cleanup activities and groundwater activities. Costs will be recovered in rates based on the average life of debt financed to fund actual expenditures. See Note 23 — Contingencies and Legal Proceedings — Contingencies — Environmental Matters.

Nuclear Decommissioning Costs.  Nuclear decommissioning costs include (1) certain deferred charges related to the future closure and decommissioning of TVA's nuclear generating units under the Nuclear Regulatory Commission ("NRC") requirements, (2) recognition of changes in the liability, (3) recognition of changes in the value of TVA's NDT, and (4) certain other deferred charges under the accounting rules for AROs.  These future costs can be funded through a combination of investment funds set aside in the NDT and ART and future earnings on those investment funds. Deferred charges will be recovered in rates based on the analysis of expected expenditures, contributions, and investment earnings required to recover the decommissioning costs.  See Note 1 — Summary of Significant Accounting Policies — Investment Funds.  Recovery of future decommissioning costs is dependent upon the future earnings of the NDT and ART, timing of decommissioning activities, and changes in decommissioning estimates. The regulatory asset is classified as long-term as amounts recovered are contributed to the NDT or the ART, which are restricted for future decommissioning costs. See Note 14 — Asset Retirement Obligations and Note 17 — Fair Value Measurements.

Other Non-Current Regulatory Assets. Other non-current regulatory assets consist of the following:

    Deferred Lease Asset and Other Financing Obligations. For certain leases, TVA recognized the initial finance lease and other financing asset and liability at inception of the lease or other obligation. However, the annual expense recognized in rates is equal to the annual payments, which differs from GAAP treatment for non-regulated entities. This practice results in TVA's asset balances being higher than they otherwise would have been under GAAP, with the difference representing a regulatory asset related to the lease or other financing obligation. These costs will be amortized over the respective lease or other financing obligation terms as payments are made. As the costs associated with this regulatory asset are not currently being considered in rates and the asset is expected to increase over the next year, the regulatory asset has been classified as long-term.

Debt Reacquisition Costs.  Reacquisition expenses, call premiums, and other related costs, such as unamortized debt issue costs associated with redeemed Bond issues, are deferred and amortized (accreted) on a straight-line basis over the weighted average life of TVA's debt portfolio. Because timing of additional reacquisition expenses and changes to the weighted average life of the debt are uncertain, the regulatory asset is classified as long-term.

Retirement Removal Costs.  Retirement removal costs, net of salvage, that are not legally required are recognized as a regulatory asset. Net removal costs are amortized over a one-year period subsequent to completion of the removal activities. TVA treats this regulatory asset as long-term in its entirety primarily because it relates to assets that are long-term in nature.
Fuel Cost Adjustment Tax Equivalents.  The fuel cost adjustment includes a provision related to the current funding of the future payments TVA will make.  As TVA records the fuel cost adjustment, five percent of the calculation that relates to a future asset or liability for tax equivalent payments is recorded as a current regulatory liability and paid or refunded in the following year.
v3.25.3
Variable Interest Entities (Text Block)
 12 Months Ended
Sep. 30, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Variable Interest Entities .  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 ("SSSL") 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.

Johnsonville VIE

In October 2024, TVA entered into an $800 million construction management agreement and lease financing arrangement with Johnsonville Aeroderivative Combustion Turbine Generation LLC ("JACTG") for the completion and lease by TVA of the Johnsonville Aeroderivative Combustion Turbine Facility ("Johnsonville Facility"). JACTG is a special single-purpose limited liability company formed in September 2024 to finance the Johnsonville Facility through a $720 million secured note issuance (the "JACTG notes") and the issuance of $80 million of membership interests subject to mandatory redemption. The membership interests were purchased by Johnsonville Holdco LLC ("JHLLC"). JHLLC is a special single-purpose entity, also formed in September 2024, established to acquire and hold the membership interests in JACTG. A non-controlling interest in JHLLC 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 JHLLC in JACTG were purchased with proceeds from the issuance of $80 million of secured notes (the "JHLLC notes") and are subject to mandatory redemption pursuant to a schedule of amortizing, semi-annual payments due each April 1 and October 1, with a final payment due in October 2054. The payment dates for the mandatorily redeemable membership interests are the same as those of the JHLLC notes. The sale of the JACTG notes, the membership interests in JACTG, and the JHLLC notes closed in October 2024. The JACTG notes are secured by TVA's lease payments, and the JHLLC notes are secured by JHLLC's investment in, and amounts receivable from, JACTG. TVA's lease payments to JACTG are equal to and payable on the same dates as JACTG's and JHLLC's semi-annual debt service payments. In addition to the lease payments, TVA pays administrative and miscellaneous expenses incurred by JACTG and JHLLC. 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 JACTG and JHLLC, TVA has determined that it has a variable interest in both of these entities. Based on its analysis, TVA has concluded that it is the primary beneficiary of JACTG and JHLLC and, as such, is required to account for the VIEs on a consolidated basis. JHLLC's membership interests in JACTG are eliminated in consolidation.

Impact on Consolidated Financial Statements

    The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, SCCG, JACTG, and JHLLC as of September 30, 2025 and 2024, as reflected on the Consolidated Balance Sheets, are as follows:
Summary of Impact of VIEs on Consolidated Balance Sheets
At September 30
(in millions)
 20252024
Current liabilities 
Accrued interest$29 $9 
Accounts payable and accrued liabilities1 1 
Current maturities of long-term debt of variable interest entities49 37 
Total current liabilities
79 47 
Other liabilities
Other long-term liabilities14 16 
Long-term debt, net
Long-term debt of variable interest entities, net1,632 897 
Total liabilities$1,725 $960 

Interest expense of $86 million, $46 million, and $48 million related to debt of VIEs and membership interests of variable interest entity subject to mandatory redemption is included on the Consolidated Statements of Operations for the years ended September 30, 2025, 2024, and 2023, respectively.

At September 30, 2025, TVA had outstanding debt of VIEs of $1.7 billion and outstanding membership interests subject to mandatory redemption (including current portion) of $16 million issued by one of its VIEs of which it is the primary beneficiary. The following table sets forth TVA's future payments at September 30, 2025:
Maturities Due in the Year Ending September 30
(in millions)
20262027202820292030Thereafter
Long-term debt of VIEs including current maturities(1)
$49 $51 $53 $56 $58 $1,431 
Membership interests of variable interest entity subject to mandatory redemption1 1 1 2 2 9 
Note
(1) Long-term debt of VIEs does not include non-cash item of unamortized debt issue costs of $17 million.

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.
v3.25.3
Other Long-Term Liabilities
 12 Months Ended
Sep. 30, 2025
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 environmental compliance and remediation and long-term project cost accruals. The table below summarizes the types and amounts of Other long-term liabilities:
Other Long-Term Liabilities
At September 30
(in millions)
 2025
2024(1)
Interest rate swap liabilities$643 $792 
Environmental compliance and remediation costs274 226 
Long-term project cost accruals204 140 
Currency swap liabilities108 109 
Operating lease liabilities63 88 
Advances for construction61 55 
Long-term deferred compensation54 50 
EnergyRight® financing obligation
53 52 
Long-term deferred revenue39 48 
Accrued long-term service agreements25 7 
Commodity contract derivative liabilities12 64 
Other70 81 
Total other long-term liabilities$1,606 $1,712 
Note
(1) At September 30, 2024, $21 million previously classified as Other (a component of Other long-term liabilities) has been reclassified to Environmental compliance and remediation costs ($14 million) and Accrued long-term service agreements ($7 million).
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 16 — 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.

Environmental Compliance and Remediation Costs. Environmental compliance and remediation costs represent certain costs associated with environmental remediation activities, including but not limited to those involving environmental cleanup activities and groundwater activities. The current and long-term portions of environmental compliance and remediation costs are reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA's Consolidated Balance Sheets. At September 30, 2025 and 2024, the current amount of the environmental compliance and remediation costs reported in Accounts payable and accrued liabilities was $52 million and $3 million, respectively.

Long-Term Project Cost Accruals. Long-term project cost accruals represent the unpaid liability associated with major construction projects and other project expenditures. TVA accrues these costs based on level of completion of the vendor's performance obligation, and the long-term portion represents amounts that will not be paid within the next 12 months. The current and long-term portions of Long-term project cost accruals are reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA's Consolidated Balance Sheets. At September 30, 2025 and 2024, the current amount of the long-term project cost accruals reported in Accounts payable and accrued liabilities was $256 million and $124 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 16 — 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.

Operating Lease Liabilities. TVA's operating leases consist primarily of railcars, equipment, real estate/land, and power generating facilities. At September 30, 2025 and 2024, the current portion of TVA's operating leases reported in Accounts payable and accrued liabilities was $46 million and $63 million, respectively. See Note 9 — Leases for more information regarding leases.

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 September 30, 2025 and 2024, the current amount of advances for construction recorded in Accounts payable and accrued liabilities was $155 million and $60 million, respectively.

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 September 30, 2025 and 2024, the current amount of deferred compensation recorded in Accounts payable and accrued liabilities was $70 million and $74 million, respectively.

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 September 30, 2025 and 2024, the carrying amount of the financing obligation reported in Accounts payable and accrued liabilities was $13 million. See Note 10 — Other Long-Term Assets for information regarding the associated loans receivable.

Long-Term Deferred Revenue. Long-term deferred revenue represents payments received that exceed services rendered resulting in the deferral of revenue. This 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 recorded in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA’s Consolidated Balance Sheets. At September 30, 2025 and 2024, the current amount of deferred revenue recorded in Accounts payable and accrued liabilities was $25 million and $28 million, respectively.

Accrued 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, parts received and services rendered exceed payments made. The current and long-term portions of the resulting obligation are recorded in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA's Consolidated Balance Sheets. At September 30, 2025 and 2024, the current amount of accrued long-term service agreements recorded in Accounts payable and accrued liabilities was $17 million and $16 million, respectively.

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 16 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Contract Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.
v3.25.3
Debt and Other Obligations
 12 Months Ended
Sep. 30, 2025
Debt Disclosure [Abstract]  
Debt and Other Obligations .  Debt and Other Obligations
General

The TVA Act authorizes TVA to issue Bonds in an amount not to exceed $30.0 billion at any time.  At September 30, 2025, TVA had only two types of Bonds outstanding: power bonds and discount notes.  Power bonds have maturities between one year and 50 years, and discount notes have maturities of less than one year.  Power bonds and discount notes are both issued pursuant to Section 15d of the TVA Act and pursuant to the Basic Tennessee Valley Authority Power Bond Resolution adopted by the TVA Board on October 6, 1960, as amended on September 28, 1976, October 17, 1989, and March 25, 1992 (the "Basic Resolution").  Bonds are not obligations of the U.S., and the U.S. does not guarantee the payments of principal or interest on Bonds.

Power bonds and discount notes rank on parity and have first priority of payment from net power proceeds, which 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 equivalent payments, 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.

TVA considers its scheduled payments under its lease financing arrangements involving John Sevier CCF, Southaven CCF, and Johnsonville Facility as costs of operating, maintaining, and administering its power properties. Costs of operating, maintaining, and administering TVA's power properties have priority over TVA's payments on the Bonds.  Once net power proceeds have been applied to payments on power bonds and discount notes as well as any other Bonds that TVA may issue in the future that rank on parity with or subordinate to power bonds and discount notes, Section 2.3 of the Basic Resolution provides that the remaining net power proceeds shall be used only for (1) minimum payments into the U.S. Treasury required by the TVA Act as repayment of, and as a return on, the Power Program Appropriation Investment; (2) investment in power system assets; (3) additional reductions of TVA's capital obligations; and (4) other lawful purposes related to TVA's power business.

The TVA Act and the Basic Resolution each contain two bond tests: the rate test and the bondholder protection test.  Under the rate test, TVA must charge rates for power which will produce gross revenues sufficient to provide funds for, among other things, debt service on outstanding Bonds.  As of September 30, 2025, TVA was in compliance with the rate test. Under the bondholder protection test, TVA must, in successive five-year periods, use an amount of net power proceeds at least equal to the sum of (1) the depreciation accruals and other charges representing the amortization of capital expenditures and (2) the net proceeds from any disposition of power facilities for either the reduction of its capital obligations (including Bonds and the Power Program Appropriation Investment) or investment in power assets. TVA met the bondholder protection test for the five-year period ended September 30, 2025 and must next meet the bondholder protection test for the five-year period ending September 30, 2030.

Secured Debt of VIEs

In October 2024, JACTG issued secured notes totaling $720 million that bear interest at a rate of 5.078 percent. Also in October 2024, JHLLC issued secured notes totaling $80 million that bear interest at a rate of 5.74 percent. The JACTG notes and the JHLLC notes require amortizing semi-annual payments on each April 1, and October 1, and mature on October 1, 2054. See Note 12 — Variable Interest Entities — Johnsonville VIEs. TVA used the proceeds from the transaction primarily to fund the construction of the Johnsonville Facility.
In August 2013, SCCG issued secured notes totaling $360 million that bear interest at a rate of 3.846 percent. The SCCG notes require amortizing semi-annual payments on each February 15 and August 15, and mature on August 15, 2033. Also in August 2013, SCCG issued $40 million of membership interests subject to mandatory redemption. The proceeds from the secured notes issuance and the issuance of the membership interests were paid to TVA in accordance with the terms of the Southaven head lease. See Note 12 — Variable Interest Entities — Southaven VIE. TVA used the proceeds from the transaction primarily to fund the acquisition of the Southaven CCF from SSSL.

In January 2012, JSCCG issued secured notes totaling $900 million in aggregate principal amount that bear interest at a rate of 4.626 percent. Also in January 2012, Holdco issued secured notes totaling $100 million that bear interest at a rate of 7.1 percent. The JSCCG notes and the Holdco notes require amortizing semi-annual payments on each January 15 and July 15, and mature on January 15, 2042. The Holdco notes require a $10 million balloon payment upon maturity. See Note 12 — Variable Interest Entities — John Sevier VIEs. TVA used the proceeds from the transaction to meet its requirements under the TVA Act.

Secured debt of VIEs, including current maturities, outstanding at September 30, 2025 and 2024 totaled $1.7 billion and $934 million, respectively.

Short-Term Debt

    The following table provides information regarding TVA's short-term borrowings:
Short-Term Borrowings
At September 30
 20252024
Gross amount outstanding - discount notes (in millions)$— $1,168 
Weighted average interest rate - discount notes— %4.76 %

Put Options

TVA has two issues of Putable Automatic Rate Reset Securities ("PARRS") outstanding.  After a fixed-rate period of five years, the coupon rate on the PARRS may automatically be reset downward under certain market conditions on an annual basis.  The coupon rate reset on the PARRS is based on a calculation.  For both series of PARRS, the coupon rate will reset downward on the reset date if the rate calculated is below the then-current coupon rate on the Bond.  The calculation dates, potential reset dates, and terms of the calculation are different for each series.  The coupon rate on the 1998 Series D PARRS may be reset on June 1 (annually) if the sum of the five-day average of the 30-Year Constant Maturity Treasury ("CMT") rate for the week ending the last Friday in April, plus 94 basis points, is below the then-current coupon rate.  The coupon rate on the 1999 Series A PARRS may be reset on May 1 (annually) if the sum of the five-day average of the 30-Year CMT rate for the week ending the last Friday in March, plus 84 basis points, is below the then-current coupon rate.  The coupon rates may only be reset downward, but investors may request to redeem their Bonds at par value in conjunction with a coupon rate reset for a limited period of time prior to the reset dates under certain circumstances.

The coupon rate for the 1998 Series D PARRS, which mature in June 2028, has been reset eight times, from an initial rate of 6.750 percent to the current rate of 2.134 percent.  In connection with these resets, $318 million of the Bonds have been redeemed; therefore, $256 million of the Bonds were outstanding at September 30, 2025.  The coupon rate for the 1999 Series A PARRS, which mature in May 2029, has been reset seven times, from an initial rate of 6.50 percent to the current rate of 2.216 percent.  In connection with these resets, $316 million of the Bonds have been redeemed; therefore, $208 million of the Bonds were outstanding at September 30, 2025.

Due to the contingent nature of the put option on the PARRS, TVA determines whether the PARRS should be classified as long-term debt or current maturities of long-term debt by calculating the expected reset rate for the Bonds on the calculation dates, described above.  If the determination date for reset is before the balance sheet date of the reporting period and the expected reset rate is less than the then-current coupon rate on the PARRS, the PARRS are included in current maturities. Otherwise, the PARRS are included in long-term debt.  
Debt Securities Activity

The table below summarizes the long-term debt securities activity for the years ended September 30, 2025 and 2024.
Debt Securities Activity
For the years ended September 30
(in millions)
396720252024
Issues
Variable interest entities$800 $— 
2024 Series A(1)
— 1,000 
2025 Series A(2)
1,250 — 
2025 Series B(3)
1,500 — 
2025 Series C(4)
1,250 — 
Discount on debt issues(33)(9)
Total$4,767 $991 
Redemptions/Maturities(5)
 
2009 Series B$22 $22 
2014 Series A— 1,000 
2020 Series A1,000 — 
Total redemptions/maturities of power bonds1,022 1,022 
Debt of variable interest entities41 35 
Total redemptions/maturities of debt$1,063 $1,057 
Notes
(1) The 2024 Series A Bonds were issued at 99.109 percent of par.
(2) The 2025 Series A Bonds were issued at 98.517 percent of par.
(3) The 2025 Series B Bonds were issued at 99.360 percent of par.
(4) The 2025 Series C Bonds were issued at 99.593 percent of par.
(5) All redemptions were at 100 percent of par.

Debt Outstanding

    Total debt outstanding at September 30, 2025 and 2024, consisted of the following: 
Short-Term Debt
At September 30
(in millions)
 
CUSIP or Other Identifier
 
Maturity
 
Coupon Rate		20252024
Short-term debt, net of discounts$— $1,167 
Current maturities of long-term debt of variable interest entities49 37 
Current maturities of power bonds issued at par
880591EW85/15/20250.750%— 1,000 
880591CJ9(1)
11/1/20256.750%1,350 — 
880591EF512/15/20253.770%— 1 
880591EF56/15/20263.770%20 21 
Total current maturities of power bonds issued at par  1,370 1,022 
Total current debt outstanding, net  $1,419 $2,226 
Notes
(1) On November 1, 2025, TVA redeemed a $1.4 billion power bond due to maturity. TVA's next significant power bond maturity is $1.0 billion in February 2027.
Long-Term Debt
At September 30
(in millions)
 
CUSIP or Other Identifier
 
Maturity
Coupon
Rate		2025 Par2024 ParStock Exchange Listings
880591CJ911/1/20256.750%$— $1,350 New York, Hong Kong, Luxembourg, Singapore
880591EU22/1/20272.875%1,000 1,000 New York
880591EZ13/15/20283.875%1,000 1,000 New York
880591300(1)
6/1/20282.134%256 256 New York
880591409(1)
5/1/20292.216%208 208 New York
880591DM15/1/20307.125%1,000 1,000 New York, Luxembourg
880591FE78/1/20303.875%1,250 — New York
880591EX69/15/20311.500%500 500 New York
880591DP46/7/20326.587%
(2)
337 
(3)
335 
(3)
New York, Luxembourg
880591DV17/15/20334.700%472 472 New York, Luxembourg
880591EF56/15/20343.770%96 116 None
880591FB38/1/20344.375%1,000 1,000 New York
880591FD95/15/20354.875%1,500 — New York
880591DX76/15/20354.650%436 436 New York
880591CK64/1/20365.980%121 121 New York
880591CS94/1/20365.880%1,500 1,500 New York
880591CP51/15/20386.150%1,000 1,000 New York
880591ED06/15/20385.500%500 500 New York
880591EH19/15/20395.250%2,000 2,000 New York
880591EP312/15/20423.500%1,000 1,000 New York
880591DU36/7/20434.962%
(2)
202 
(3)
201 
(3)
New York, Luxembourg
880591EB41/15/20484.875%500 500 New York, Luxembourg
880591EY49/15/20524.250%500 500 New York
880591FC12/1/20555.250%1,250 — New York
880591DZ24/1/20565.375%1,000 1,000 New York
880591EJ79/15/20604.625%1,000 1,000 New York
880591ES79/15/20654.250%1,000 1,000 New York
Subtotal20,628 17,995  
Unamortized discounts, premiums, issue costs, and other (167)(128) 
Total long-term outstanding power bonds, net 20,461 17,867  
Long-term debt of VIEs, net1,632 897 
Total long-term debt, net$22,093 $18,764 
Notes
(1) TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions.  See Put Options above.
(2) The coupon rate represents TVA's effective interest rate.
(3) CUSIP numbers 880591DP4 and 880591DU3 include total net exchange gain from currency transactions of $59 million and $62 million at September 30, 2025 and 2024, respectively.
  
 
Maturities Due in the Year Ending September 30
(in millions)
20262027202820292030ThereafterTotal
Long-term power bonds including current maturities(1)
$1,370 $1,020 $1,272 $220 $2,262 $15,913 $22,057 
Notes
(1) Long-term power bonds do not include non-cash items of foreign currency exchange gain of $59 million, unamortized debt issue costs of $54 million, or net discount on sale of Bonds of $113 million.

Credit Facility Agreements

TVA has funding available under four 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 September 30, 2025 and 2024, there were $498 million and $566 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 16 — 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 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 revolving credit facilities:
Summary of Credit Facilities
At September 30, 2025
(in millions)
Maturity DateFacility LimitLetters of Credit OutstandingCash BorrowingsAvailability
March 2026$150 $38 $— $112 
March 20271,000 135 — 865 
February 2028500 215 — 285 
September 20301,000 110 — 890 
     Total$2,650 $498 $— $2,152 

TVA and the U.S. Treasury, pursuant to the 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 2026 with a maturity date of September 30, 2026. 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 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 September 30, 2025. The availability of this credit facility may be impacted by how the U.S. government addresses the possibility of approaching its debt limit.
v3.25.3
Risk Management Activities and Derivative Transactions
 12 Months Ended
Sep. 30, 2025
Derivative Instruments and Hedging Activities Disclosure [Abstract]  
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)
For the years ended September 30
(in millions)
Derivatives in Cash Flow Hedging RelationshipObjective of Hedge TransactionAccounting for Derivative
Hedging Instrument		20252024
Currency swapsTo 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$1 $25 
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
For the years ended September 30
(in millions)
Derivatives in Cash Flow Hedging Relationship20252024
Currency swaps$3 $48 
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 $14 million of gains from 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)
For the years ended September 30
(in millions)
 
Derivative TypeObjective of DerivativeAccounting for Derivative Instrument20252024
Interest rate swapsTo 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		$45 $(31)
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)
(93)(295)
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 liabilities and assets. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the years ended September 30, 2025 and 2024.
(2) Of the amount recognized in 2025, $77 million and $16 million were reported in Fuel expense and Purchased power expense, respectively. Of the amount recognized in 2024, $245 million and $50 million were reported in Fuel expense and Purchased power expense, respectively.
Fair Values of TVA Derivatives
At September 30
(in millions)
 20252024
Derivatives That Receive Hedge Accounting Treatment:
 BalanceBalance Sheet PresentationBalanceBalance Sheet Presentation
Currency swaps    
£250 million Sterling
$(47)
Accounts payable and accrued liabilities $(4); Other long-term liabilities $(43)
$(49)
Accounts payable and accrued liabilities $(4); Other long-term liabilities $(45)
£150 million Sterling
(68)
Accounts payable and accrued liabilities $(3); Other long-term liabilities $(65)
(67)
Accounts payable and accrued liabilities $(3); Other long-term liabilities $(64)
Derivatives That Do Not Receive Hedge Accounting Treatment:
 BalanceBalance Sheet PresentationBalanceBalance Sheet Presentation
Interest rate swaps    
$1.0 billion notional
$(526)
Accounts payable and accrued liabilities $(13); Accrued interest $(28); Other long-term liabilities $(485)
$(622)
Accounts payable and accrued liabilities $(10), Accrued interest $(26);
Other long-term liabilities
$(586)
$476 million notional
(172)
Accounts payable and accrued liabilities $(5); Accrued interest $(9); Other long-term liabilities $(158)
(218)
Accounts payable and accrued liabilities $(3), Accrued interest $(9);
Other long-term liabilities
$(206)
Commodity contract derivatives 10 
Other current assets $14; Other long-term assets $2; Accounts payable and accrued liabilities $(2); Other long-term liabilities $(4)
2 
Other current assets $5; Other long-term assets $2; Accounts payable and accrued liabilities $(3); Other long-term liabilities $(2)
Commodity derivatives under the FHP(57)
Other long-term assets $8; Accounts payable and accrued liabilities $(57); Other long-term liabilities $(8)
(161)
Accounts payable and accrued liabilities $(99); Other long-term liabilities $(62)

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 the following currency swaps outstanding at September 30, 2025:
Currency Swaps Outstanding
Effective Date of Currency Swap ContractAssociated TVA Bond Issues Currency ExposureExpiration Date of SwapOverall Effective
Cost to TVA
2001£250 million20326.587%
2003£150 million20434.962%

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 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 years ended September 30, 2025 and 2024, the changes in fair market value of the interest rate swaps resulted in the reduction in unrealized losses of $145 million and the increase in unrealized losses of $182 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 Contract Derivatives. TVA enters into certain commodity contract derivatives for natural gas that require physical delivery of the contracted quantity. TVA may also enter into PPAs 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 September 30, 2025, TVA's natural gas commodity contract derivatives had terms of up to 10 years.
Commodity Contract Derivatives 
At September 30
 20252024
 
Number of Contracts
Notional AmountFair Value (MtM)
(in millions)		Number of ContractsNotional Amount
Fair Value (MtM)
(in millions)
Natural gas contract derivatives53562 million mmBtu$10 45321 million mmBtu$2 

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 September 30, 2025, TVA's natural gas swap contracts under the FHP had remaining terms of up to four years.

Commodity Derivatives under Financial Hedging Program(1)
At September 30
20252024
Number of Contracts
Notional Amount
Fair Value (MtM)
(in millions)
Number of Contracts
Notional Amount
Fair Value (MtM)
(in millions)
Natural gas swap contracts295300 million mmBtu$(57)126230 million mmBtu$(161)
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.
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)
At September 30
(in millions)
20252024
Assets
Commodity contract derivatives 16 7 
Commodity derivatives under the FHP(2)
8 — 
Total derivatives subject to master netting or similar arrangement$24 $7 
Liabilities
Currency swaps$115 $116 
Interest rate swaps(3)
698 840 
Commodity contract derivatives6 5 
Commodity derivatives under the FHP(2)
65 161 
Total derivatives subject to master netting or similar arrangement$884 $1,122 
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 September 30, 2025 or 2024.
(2) At September 30, 2025, the gross derivative asset and gross derivative liability was $28 million and $85 million, respectively, with offsetting amounts for each totaling $20 million. At September 30, 2024, the gross derivative asset and gross derivative liability were $4 million and $165 million, respectively, with offsetting amounts for each totaling $4 million.
(3) Letters of credit of approximately $442 million and $535 million were posted as collateral at September 30, 2025 and 2024, respectively, to partially secure the liability positions of one of the interest rate swaps in accordance with the collateral requirements for this derivative.

Other Derivative Instruments

Investment Fund Derivatives.  Investment funds consist primarily of funds held in the NDT, ART, SERP, DCP, and RP.  See Note 17 — 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 September 30, 2025 and 2024, the NDT held investments in forward contracts to purchase debt securities. The fair values of these derivatives were in net asset positions totaling $16 million and $11 million at September 30, 2025 and 2024, 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 September 30, 2025, the aggregate fair value of all derivative instruments with credit-risk related contingent features that were in a liability position was $884 million.  TVA's collateral obligations at September 30, 2025, under these arrangements were $456 million, for which TVA had posted $442 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 S&P Global Ratings ("S&P") 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 $1.9 billion and $1.7 billion of receivables from power sales outstanding at September 30, 2025 and 2024, respectively, nearly all of the counterparties were rated investment grade. The majority of 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 either delivered power or the replacement of open positions of longer-term purchased power or fuel agreements. 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 4 — Accounts Receivable, Net, and Note 10 — Other Long-Term Assets.
TVA had revenue from two LPCs that collectively accounted for 17 percent of total operating revenues for both the years ended September 30, 2025 and 2024.

Suppliers.  TVA assesses potential supplier performance risks, including procurement of fuel, purchased power, parts, and services. If suppliers are unable or unwilling to perform under TVA's existing contracts, if TVA is unable to obtain similar services or supplies from other vendors, or if there are significant changes to tariffs impacting suppliers, 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 supply chain pressures resulting from inflation, tariffs and other trade restrictions, material constraints, and labor availability. These factors have contributed to project delays, limited availability of critical materials, and increased costs for both materials and labor. Although these challenges have been managed with limited disruption to business operations thus far, continued or escalating pressures could result in more substantial operational impacts and increased pressure on 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 uses 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 with natural gas, TVA intends to leverage its storage and balancing services and/or replace the volume with a third party to ensure reliability of generation.

    Coal. To help support a reliable coal supply, TVA maintained contracts with multiple suppliers at September 30, 2025. These contracts source coal from several diverse geographic regions across the U.S., with deliveries made via both barge and rail. Coal suppliers have faced mounting financial pressures driven by emerging technologies, evolving regulatory frameworks, and shifting market dynamics. These challenges have strained the balance between coal demand and available supply. TVA is actively evaluating recent regulatory developments that may impact its coal procurement strategy and long-term generation planning.

    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.

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

Other Suppliers. Solar supply chain constraints, commodity price increases, legislative changes, trade policy issues, and investigations into and affecting solar panel imports have created challenges for the U.S. solar industry including TVA's solar portfolio.
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 September 30, 2025, 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 September 30, 2025, the forward natural gas contracts were with counterparties whose ratings ranged from B1 to A1.
v3.25.3
Fair Value Measurements
 12 Months Ended
Sep. 30, 2025
Fair Value Disclosures [Abstract]  
Fair Value Measurements
17.  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, DCP, and RP 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 September 30, 2025, Investment funds were comprised of $5.6 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 $3.7 billion and $1.7 billion, respectively, at September 30, 2025.

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 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 ("TIPS"), and
real estate investment trust 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. Cash equivalents and other short-term investments are highly liquid securities with maturities of less than three months and 12 months, respectively. These consist primarily of discount securities such as repurchase agreements and U.S. Treasury bills. These securities may be priced at cost, which approximates fair value due to the short-term nature of the instruments. These securities are classified as Level 2. Active market pricing may be utilized for U.S. Treasury bills, which are classified as Level 1.

    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 $361 million, private real assets of $138 million, and private credit of $117 million at September 30, 2025. The ART had unfunded commitments related to limited partnerships in private equity of $145 million, private real assets of $89 million, and private credit of $57 million at September 30, 2025. 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 — Cost-Based Regulation and Note 11 — 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)
For the years ended September 30
(in millions)
FundFinancial Statement Presentation20252024
NDT
Regulatory assets(2)
$221 $324 
ART
Regulatory assets(3)
116 171 
SERPOther income, net3 14 
DCPOther income, net1 2 
Notes
(1) The unrealized gains for the RP were less than $1 million for both the years ended September 30, 2025 and 2024 and therefore were not represented in the table above.
(2) Includes $10 million and $93 million of unrealized gains related to NDT equity securities (excluding commingled funds) for the years ended September 30, 2025 and 2024, respectively.
(3) Includes $7 million and $36 million of unrealized gains related to ART equity securities (excluding commingled funds) for the years ended September 30, 2025 and 2024, respectively.

Currency and Interest Rate Swap Derivatives

See Note 16 — 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 16 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Contract 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 initial 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 2024) 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 less than $1 million decrease in the fair value of assets and a $3 million decrease in the fair value of liabilities at September 30, 2025.

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 September 30, 2025 and 2024. 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 September 30, 2025
(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$844 $— $— $844 
Government debt securities(1)(2)
423 50 — 473 
Corporate debt securities(3)
— 411 — 411 
Mortgage and asset-backed securities— 40 — 40 
Institutional mutual funds367 — — 367 
Forward debt securities contracts— 16 — 16 
Cash equivalents and other short-term investments(2)(4)
111 163 — 274 
Private equity funds measured at net asset value(5)
— — — 875 
Private real asset funds measured at net asset value(5)
— — — 467 
Private credit funds measured at net asset value(5)
— — — 278 
Commingled funds measured at net asset value(5)
— — — 1,528 
Total investments1,745 680 — 5,573 
Commodity contract derivatives— 16 — 16 
Commodity derivatives under the FHP— 8 — 8 
Total$1,745 $704 $— $5,597 
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(6)
$— $115 $— $115 
Interest rate swaps— 698 — 698 
Commodity contract derivatives— 6 — 6 
Commodity derivatives under the FHP— 65 — 65 
Total$— $884 $— $884 
Notes
(1) Includes obligations of government-sponsored entities.
(2) There are $423 million of U.S. Treasury securities in Level 1 Government debt securities and $111 million of U.S. Treasury securities in Level 1 Cash equivalents and other short-term investments for a total of $534 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.
(3) Includes both U.S. and foreign debt.
(4) Includes $60 million net payables (interest receivable, dividends receivable, receivables for investments sold, and payables for investments purchased), and $124 million of repurchase agreements in Level 2 Cash equivalents and other short-term investments.
(5) 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.
(6) TVA records currency swaps net of cash collateral received from or paid to the counterparty, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 16 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.
Fair Value Measurements
At September 30, 2024
(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$770 $— $— $770 
Government debt securities(1)(2)
400 57 — 457 
Corporate debt securities(3)
— 378 — 378 
Mortgage and asset-backed securities— 43 — 43 
Institutional mutual funds342 — — 342 
Forward debt securities contracts— 11 — 11 
Cash equivalents and other short-term investments(2)(4)
95 183 — 278 
Private equity funds measured at net asset value(5)
— — — 738 
Private real asset funds measured at net asset value(5)
— — — 432 
    Private credit funds measured at net asset value(5)
— — — 219 
Commingled funds measured at net asset value(5)
— — — 1,300 
Total investments1,607 672 — 4,968 
Commodity contract derivatives— 7 — 7 
Total$1,607 $679 $— $4,975 
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(6)
$— $116 $— $116 
Interest rate swaps— 840 — 840 
Commodity contract derivatives— 5 — 5 
Commodity derivatives under the FHP— 161 — 161 
Total$— $1,122 $— $1,122 
Notes
(1) Includes obligations of government-sponsored entities.
(2) There are $400 million of U.S. Treasury securities in Level 1 Government debt securities and $95 million of U.S. Treasury securities in Level 1 Cash equivalents and other short-term investments for a total of $495 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.
(3) Includes both U.S. and foreign debt.
(4) Includes $78 million net payables (interest receivable, dividends receivable, receivables for investments sold, and payables for investments purchased), and $174 million of repurchase agreements in Level 2 Cash equivalents and other short-term investments.
(5) 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, estimated benchmark yields, 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.
(6) TVA records currency swaps net of cash collateral received from or paid to the counterparty, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 16 — 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 September 30, 2025 and 2024, 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 September 30, 2025 and 2024, were as follows:
Estimated Values of Financial Instruments Not Recorded at Fair Value
(in millions)
 At September 30, 2025At September 30, 2024
 Valuation ClassificationCarrying
Amount		Fair
Value		Carrying
Amount		Fair
Value
EnergyRight® receivables, net (including current portion)
Level 2$57 $57 $56 $56 
Loans and other long-term receivables, net (including current portion)Level 286 80 105 99 
EnergyRight® financing obligations (including current portion)
Level 266 74 66 74 
Membership interests of VIEs subject to mandatory redemption (including current portion)Level 216 18 17 19 
Long-term outstanding power bonds, net (including current maturities)Level 221,831 21,967 18,889 19,416 
Long-term debt of VIEs, net (including current maturities)Level 21,681 1,696 934 966 

The carrying values 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.
v3.25.3
Other Income (Expense), Net
 12 Months Ended
Sep. 30, 2025
Other Income and Expenses [Abstract]  
Other Income (Expense), Net
19.  Other Income, Net

Income and expenses not related to TVA's operating activities are summarized in the following table:
Other Income, Net
For the years ended September 30
(in millions)
 202520242023
Interest income$52 $42 $34 
External services28 17 15 
Gains (losses) on investments14 23 13 
Miscellaneous(2)(11)(1)
Total other income, net$92 $71 $61 
v3.25.3
Commitments and Contingencies
 12 Months Ended
Sep. 30, 2025
Commitments and Contingencies Disclosure [Abstract]  
Commitments and Contingencies
23. Commitments and Contingencies

Commitments

    Power Purchase Obligations.  TVA has contracted with various independent power producers and LPCs for additional capacity to be made available to TVA. Several of these agreements have contractual minimum payments and are accounted for as either finance or operating leases.  In total, these agreements provide 5,938 megawatts ("MW") of summer net capability.  The remaining terms of the agreements range up to 23 years.  Additionally, TVA has contracted with regional transmission organizations to reserve 3,750 MW of transmission service to support purchases from the market and certain PPAs. The remaining terms of these agreements range up to six years. TVA has recorded $696 million, $519 million, and $355 million of expense under these power purchase and transmission service agreements during 2025, 2024, and 2023, respectively.

TVA has one power purchase agreement that was negotiated as part of arranging financing for the facility. At September 30, 2025, the non-lease portion of the commitment for each of the next five years and thereafter is shown below:
 20262027202820292030Thereafter
Unconditional purchase obligation$162 $162 $162 $162 $162 $242 

Under federal law, TVA is obligated to purchase power from qualifying facilities (cogenerators and small power producers).  As of September 30, 2025, there was a combined qualifying facility capacity of 281 MW from 1,344 different generation sources, from which TVA purchased power under this law.  

Unfunded Loan Commitments. At September 30, 2025, TVA had no commitments under unfunded loan commitments for 2026 through 2030.

Other Commitments. See Note 9 — Leases, Note 12 — Variable Interest Entities, Note 15 — Debt and Other Obligations, and Note 21 — Benefit Plans for the obligations and commitments attributable to leases, VIEs and membership interests of VIEs subject to mandatory redemption, leaseback obligations, and the retirement plan, respectively.
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 $500 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 $16.3 billion in coverage.

Federal law requires that each 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 $122 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 $50 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 14 — Asset Retirement Obligations.

Nuclear Decommissioning.  Provision for decommissioning costs of nuclear generating units is based on options authorized by the NRC procedures to dismantle and decontaminate the facilities to meet the NRC criteria for license termination. At September 30, 2025, $4.0 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 17 — 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 11 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Note 14 — Asset Retirement Obligations.

Non-Nuclear Decommissioning.  At September 30, 2025, $6.4 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 17 — 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 11 — Regulatory Assets and Liabilities — Non-Nuclear Decommissioning Costs and Note 14 — 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 evolve.

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.  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 drive up costs associated with, and delay or prevent permitting of, new fossil fuel facilities and related infrastructure in favor of renewable energy projects.

Compliance with the 2015 CCR Rule required implementation of a groundwater monitoring program, additional engineering, evaluation of authorized closure methods, coordination with certain state authorities, and ongoing analysis at each TVA CCR unit. As further analyses are performed, including evaluation of monitoring results, there is the potential for additional costs for investigation and/or remediation. In addition, on May 8, 2024, EPA published its Legacy CCR Rule, which expands the scope of the existing regulatory requirements of the 2015 CCR Rule to include two additional classes of CCR units: Legacy SIs and CCRMUs. As a result of the enactment of the final rule, during 2024, TVA recorded additional estimated AROs and recorded a corresponding regulatory asset due to AROs being associated with closed sites and asset retirement costs having been fully depreciated. However, the amounts recorded are subject to various uncertainties, and actual amounts may differ materially based upon a number of factors, including, but not limited to, the outcome of legal challenges to the Legacy CCR Rule, ongoing evaluations of the number and scope of newly regulated units, determinations on final closure requirements and performance standards, and possible changes to the Legacy CCR Rule by EPA. See Note 14 — Asset Retirement Obligations.

In May 2024, EPA also published (1) a final rule that establishes more stringent technology-based effluent limitations for four wastewater streams from coal-fired plants, (2) a rule that strengthens and updates the Mercury and Air Toxics Standards for electric generating units to reflect recent developments in control technologies, and (3) a rule that establishes GHG emission guidelines for existing coal-fired plants and GHG performance standards for new natural gas-fired power plants. These rules are all currently being reconsidered by EPA and are also all subject to legal challenges. If these rules move forward as written and the challenges are not successful, TVA would incur substantial costs to comply with the rules.

On March 12, 2025, the EPA Administrator announced that EPA will reconsider 31 rules, including (1) regulations on power plants, (2) Mercury and Air Toxics Standards, (3) steam electric effluent limitation guidelines, (4) National Ambient Air Quality Standards for particulate matter, (5) regulations regarding regional haze, (6) the Good Neighbor Plan, and (7) CCR regulations. TVA cannot predict the outcome of such reevaluations or their impact on TVA's financial results or operations.

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 September 30, 2025 and 2024, 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 $8 million and $15 million, respectively, 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, the 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. TVA is also following a similar process pursuant to a consent order. At September 30, 2025 and 2024, TVA's estimated liability for costs associated with environmental remediation activities for the sites covered by these orders for which sufficient information is available to develop a cost estimate was approximately $319 million and $215 million, respectively, on a non-discounted basis and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. The current estimated time frame for work related to these remediation activities for which TVA has a cost estimate is through 2044.
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 TVA's activities.
 
General. At September 30, 2025, TVA had accrued $11 million of probable losses with respect to Legal Proceedings. Of the accrued amount, $9 million is included in Other long-term liabilities and $2 million is included in Accounts payable and accrued liabilities.  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.
 
Environmental Agreements. On April 14, 2011, TVA entered into two substantively similar agreements, one with the EPA and the other with Alabama, Kentucky, North Carolina, Tennessee, and three environmental advocacy groups (collectively, the "Environmental Agreements"). To resolve alleged New Source Review claims, TVA committed under the Environmental Agreements to, among other things, take now-completed actions regarding coal units and invest $290 million in certain TVA environmental projects. Of this amount, TVA had spent approximately $285 million as of September 30, 2025. Additionally, TVA holds restricted cash in an interest earning trust to fund the remaining project commitments. Any interest earned through the trust must also be spent on agreed upon environmental projects. The total remaining committed costs, including interest earned through the trust, were approximately $7 million as of September 30, 2025.
The liabilities related to the Environmental Agreements are included in Accounts payable and accrued liabilities and Other long-term liabilities on the September 30, 2025, Consolidated Balance Sheets. In conjunction with the approval of the Environmental Agreements, the TVA Board determined that it was appropriate to record TVA's obligations under the Environmental Agreements as regulatory assets, and they are included as such on the September 30, 2025, Consolidated Balance Sheets and will be recovered in rates in future periods.

Case Involving Johnsonville Aeroderivative Combustion Turbine Project. On December 22, 2022, the Southern Environmental Law Center filed a lawsuit in the U.S. District Court for the Middle District of Tennessee on behalf of the Sierra Club, alleging that TVA violated the National Environmental Policy Act ("NEPA") in deciding to build a new aeroderivative combustion turbine project at its Johnsonville facility. Both parties moved for summary judgment, and on September 30, 2024, the court granted TVA's motion for summary judgment and dismissed the lawsuit. The Sierra Club did not file an appeal within 60 days from the date of the decision, so this litigation has now ended.

Case Involving Cumberland Combined Cycle Plant. On June 14, 2023, Appalachian Voices, the Center for Biological Diversity, and the Sierra Club filed a lawsuit in the United States District Court for the Middle District of Tennessee alleging that TVA violated NEPA in deciding to build a 1,450 MW combined cycle plant at its Cumberland facility. The plaintiffs request the court, among other things, to enter a declaratory judgment that the Cumberland Environmental Impact Statement ("EIS") violated NEPA and TVA's decision to issue the Cumberland Record of Decision was arbitrary, capricious, and/or not in accordance with law; enter a declaratory judgment that TVA’s failure to supplement the Cumberland EIS violated NEPA and was arbitrary, capricious, and/or not in accordance with law; vacate the Cumberland EIS and the Cumberland Record of Decision; order TVA to prepare a revised draft EIS or supplemental EIS subject to public comment that corrects the NEPA violations identified by the plaintiffs; and enjoin further construction and operation of the Cumberland combined cycle plant until TVA has complied with NEPA. TVA filed an amended answer on September 14, 2023. On February 13, 2024, the plaintiffs filed a motion to complete the administrative record that TVA submitted in support of the EIS for this project, alleging that the administrative record submitted by TVA is incomplete. The magistrate judge issued an order granting in part and denying in part the plaintiffs' motion to complete the administrative record. TVA subsequently filed a motion challenging the magistrate judge's ruling, and TVA's motion is pending before the court. In light of the outstanding issues related to the administrative record, the court suspended the parties' summary judgment deadlines. TVA cannot predict the outcome of this litigation.

Challenge to Certificate for Cumberland Pipeline. On April 29, 2024, the Southern Environmental Law Center, on behalf of the Sierra Club and Appalachian Voices, filed a petition with the United States Court of Appeals for the District of Columbia Circuit ("D.C. Circuit") challenging the issuance by the Federal Energy Regulatory Commission ("FERC") of a certificate of public convenience for the pipeline that will need to be constructed in order for TVA to operate the Cumberland Combined Cycle Plant (the “Cumberland Pipeline”). The petitioners allege that they and their members have been and will be aggrieved by the approval, construction, and operation of the Cumberland Pipeline and are asking the D.C. Circuit to review and set aside FERC’s order approving the pipeline. The D.C. Circuit heard oral arguments on the merits on March 4, 2025, and on September 30, 2025, the D.C. Circuit issued an opinion upholding FERC's decision to issue the certificate of public convenience for the pipeline.

Case Involving Kingston Gas-Fired Plant. On October 10, 2024, Appalachian Voices, the Center for Biological Diversity, and the Sierra Club filed a lawsuit in the United States District Court for the Eastern District of Tennessee alleging that TVA violated NEPA and TVA’s least-cost planning obligations in deciding to build a gas plant at its Kingston facility. The plaintiffs requested that the court, among other things, enter a declaratory judgment that the Kingston EIS violated NEPA and that TVA's decision to issue the Kingston Record of Decision was arbitrary, capricious, and/or not in accordance with law; enter a declaratory judgment that TVA’s least-cost-planning analysis was arbitrary, capricious, and/or not in accordance with law; vacate the Kingston Final EIS and the Kingston Record of Decision; order TVA to prepare a revised draft EIS or supplemental EIS that
complies with NEPA and least-cost-planning requirements; and enjoin further construction and operation of the Kingston Gas Plant until TVA has complied with NEPA, least-cost-planning requirements, and the Administrative Procedure Act. TVA filed its answer on December 16, 2024, and filed the administrative record on May 2, 2025. The plaintiffs filed a motion to complete the administrative record on June 30, 2025, and TVA filed its response on July 30, 2025. The plaintiffs filed a reply brief on August 8, 2025. TVA cannot predict the outcome of this litigation.

Challenge to Kingston Construction Permit. On December 16, 2024, the Southern Environmental Law Center filed an appeal on behalf of Appalachian Voices challenging the construction permit that the Technical Secretary acting on behalf of the Tennessee Air Pollution Control Board issued to TVA on November 15, 2024, for the construction of natural gas generation at Kingston. Appalachian Voices alleges that TDEC unlawfully issued a construction permit that would allow TVA to construct the plant without meeting the requirements set forth in the Tennessee Air Quality Act's and Federal Clean Air Act’s Prevention of Significant Deterioration program. Among other things, Appalachian Voices is requesting that the Tennessee Air Pollution Control Board stay the effectiveness of the permit and order TDEC to revoke the permit. On January 7, 2025, TVA filed a petition to intervene in the administrative proceeding, which was granted on January 15, 2025. The parties filed competing motions for summary judgment on March 14, 2025, and oral argument on these motions was held on June 24, 2025. On August 20, 2025, the administrative law judge issued an order upholding the construction permit and denying Appalachian Voices' petition challenging the permit. Appalachian Voices did not appeal the initial order to the Tennessee Air Pollution Control Board by the deadline of September 19, 2025, so the order became final. Appalachian Voices can seek judicial review of the final order by filing a petition within 60 days of the order becoming final.
v3.25.3
Related Parties
 12 Months Ended
Sep. 30, 2025
Related Party Transactions [Abstract]  
Related Parties
TVA is a wholly-owned corporate agency of the federal government, and because of this relationship, TVA's revenues and expenses are included as part of the federal budget as a revolving fund.  TVA's purpose and responsibilities as an agency are described under the "Other Agencies" section of the federal budget.

TVA's power program and stewardship (nonpower) programs were originally funded primarily by appropriations from Congress.  In 1959, Congress passed an amendment to the TVA Act that required TVA's power program to be self-financing from power revenues and proceeds from power program financings.  While TVA's power program did not directly receive appropriated funds after it became self-financing, TVA continued to receive appropriations for certain multipurpose and other nonpower mission-related activities as well as for its stewardship activities.  TVA has not received any appropriations from Congress for any activities since 1999, and since that time, TVA has funded stewardship program activities primarily with power revenues.

The 1959 amendment to the TVA Act also required TVA, beginning in 1961, to make annual payments to the U.S. Treasury from net power proceeds as a repayment of and as a return on the Power Program Appropriation Investment until a total of $1.0 billion of the Power Program Appropriation Investment has been repaid in accordance with the 1959 amendment.   TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment in 2014. The TVA Act requires TVA to continue making payments to the U.S. Treasury as a return on the remaining $258 million of the Power Program Appropriation Investment.

TVA paid the U.S. Treasury $8 million, $7 million, and $6 million in 2025, 2024, and 2023, respectively, as a return on the Power Program Appropriation Investment.  The amount of the return on the Power Program Appropriation Investment is based on the Power Program Appropriation Investment balance at the beginning of that year and the computed average interest rate payable by the U.S. Treasury on its total marketable public obligations at the same date.  The interest rates payable by TVA on the Power Program Appropriation Investment were 3.39 percent, 3.02 percent, and 1.99 percent for 2025, 2024, and 2023, respectively.

TVA also has access to a financing arrangement with the U.S. Treasury pursuant to the TVA Act.  TVA and the U.S. Treasury entered into a memorandum of understanding under which the U.S. Treasury provides TVA with a $150 million credit facility.  This credit facility has a maturity date of September 30, 2026, and is typically renewed annually.  Access to this credit facility or other similar financing arrangements has been available to TVA since the 1960s.  See Note 15 — Debt and Other Obligations — Credit Facility Agreements.

In the normal course of business, TVA contracts with other federal agencies for sales of electricity and other services.   Transactions with agencies of the federal government were as follows:
Related Party Transactions
At or for the years ended September 30
(in millions)
 202520242023
Revenue from sales of electricity$132 $118 $120 
Other income309 273 282 
Expenditures
Operating expenses264 241 234 
Additions to property, plant, and equipment13 12 8 
Cash and cash equivalents31 31 31 
Accounts receivable, net89 81 87 
Investment funds534 495 391 
Long-term accounts receivable43 35 38 
Accounts payable and accrued liabilities41 45 42 
Long-term power bonds, net4 3 1 
Return on power program appropriation investment8 7 6 
v3.25.3
Revenue
 12 Months Ended
Sep. 30, 2025
Revenue from Contract with Customer [Abstract]  
Revenue from Contract with Customer
18. 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 the year ended September 30, 2025, and approximately 92 percent of TVA's Revenue from sales of electricity for both the years ended September 30, 2024 and 2023, 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, pandemic credits, and demand response credits allowing TVA to reduce industrial customer usage in periods of peak demand to balance system demand. The pandemic credits ended September 30, 2023. Payments are typically due within approximately one month of invoice issuance.
 
Directly served customersDirectly 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, REC sales, and certain other ancillary goods or services.
Disaggregated Revenues

During 2025, revenues generated from TVA's electricity sales were $13.5 billion and accounted for virtually all of TVA's revenues. TVA's operating revenues by state for each of the last three years are detailed in the table below:
Operating Revenues By State
For the years ended September 30
(in millions)
 202520242023
Alabama
$1,995 $1,768 $1,731 
Georgia
329 295 284 
Kentucky
850 776 773 
Mississippi
1,254 1,150 1,146 
North Carolina
88 89 89 
Tennessee
8,915 7,998 7,819 
Virginia
52 47 46 
Subtotal13,483 12,123 11,888 
Off-system sales7 8 14 
Revenue capitalized during pre-commercial plant operations(1)
(4)(3)(3)
Revenue from sales of electricity13,486 12,128 11,899 
Other revenue186 186 155 
Total operating revenues$13,672 $12,314 $12,054 
Note
(1) Represents revenue capitalized during pre-commercial operations at Johnsonville Aeroderivative CT Units 21-30 in 2025 and Paradise CT Units 5-7 in 2024.

    TVA's operating revenues by customer type for each of the last three years are detailed in the table below:
Operating Revenues by Customer Type
For the years ended September 30
(in millions)
 202520242023
Revenue from sales of electricity  
Local power companies$12,334 $11,138 $10,903 
Industries directly served1,017 868 864 
Federal agencies and other139 125 135 
Revenue capitalized during pre-commercial plant operations(1)
(4)(3)(3)
Revenue from sales of electricity13,486 12,128 11,899 
Other revenue186 186 155 
Total operating revenues$13,672 $12,314 $12,054 
Note
(1) Represents revenue capitalized during pre-commercial operations at Johnsonville Aeroderivative CT Units 21-30 in 2025 and Paradise CT Units 5-7 in 2024.

    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 to no more than 10 percent during any consecutive five-fiscal-year period, as more specifically described in the agreements. 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 $231 million, $215 million, and $199 million, respectively, for the years ended September 30, 2025, 2024, and 2023. 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 August 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 September 30, 2025, 148 LPCs had signed the Partnership Agreement with TVA, and 109 LPCs had signed a Power Supply Flexibility Agreement.
In previous years, the TVA Board approved pandemic credits, which were effective in 2023. These credits provided an annual 2.5 percent monthly base rate credit and applied to service provided to TVA's LPCs, their large commercial and industrial customers, and TVA directly served customers. For the year ended September 30, 2023, pandemic credits totaled $225 million. The pandemic credits ended September 30, 2023.

The number of LPCs by contract arrangement, the revenues derived from such arrangements for 2025, and the percentage those revenues comprised of TVA's total operating revenues for 2025, are summarized in the table below:
TVA Local Power Company Contracts
At or for the year ended September 30, 2025
Contract Arrangements(1)
Number of LPCs Revenue from Sales of Electricity to LPCs
(in millions)		Percentage of Total Operating Revenues
20-year termination notice148 $10,636 77.8 %
5-year termination notice5 1,698 12.4 %
Total153 $12,334 90.2 %
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 accounted for nine percent and eight percent, respectively, of TVA's total operating revenues in 2025, 2024, and 2023.

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 September 30, 2025.

    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 13 — 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 $321 million, $318 million, and $330 million for 2025, 2024, and 2023, 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 September 30, 2025 and 2024, the outstanding unpaid incentives were $193 million and $187 million, respectively. Incentives that have been paid out may be subject to claw back if the customer fails to meet certain program requirements.
v3.25.3
Plant Closures (Text Block)
 12 Months Ended
Sep. 30, 2025
Property, Plant and Equipment [Abstract]  
Plant Closures . Plant Closures
Background

TVA must continuously evaluate all generating assets to ensure an optimal energy portfolio that provides safe and reliable power while maintaining flexibility and fiscal responsibility to the people of the Tennessee Valley. In January 2023, TVA issued its Record of Decision to retire two coal-fired units at Cumberland Fossil Plant ("Cumberland") by the end of CY 2026 and CY 2028. In April 2024, TVA issued its Record of Decision to retire the nine coal-fired units at Kingston Fossil Plant ("Kingston") by CY 2027. TVA is evaluating the impact of retiring the balance of the coal-fired fleet by 2035, and that evaluation includes
environmental reviews and TVA Board approval. TVA is also reviewing how recent executive orders, the evolving regulatory environment, and overall system performance are impacting the operation of its coal-fired fleet. An evaluation of the continued operation of coal-fired units is being conducted and will consider material condition, plant performance, system flexibility needs, environmental requirements, grid support, and other factors.

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. 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. The cumulative impact approximates $176 million of additional depreciation since January 2023, related to this decision. In addition, TVA's decision to retire the nine units at Kingston is estimated to result in approximately $9 million of additional depreciation quarterly, which does not include any potential impact from additions or retirements to net completed plant. The cumulative impact approximates $54 million of additional depreciation since April 2024 related to this decision.

TVA also recognized $15 million, $15 million, and $14 million in Operating and maintenance expense related to additional inventory reserves for the coal-fired fleet, including Kingston, Cumberland, and Bull Run Fossil Plant, for the years ended September 30, 2025, 2024, and 2023, respectively.
v3.25.3
Leases (Text Block)
 12 Months Ended
Sep. 30, 2025
Leases [Abstract]  
Lessee, Operating Leases . Leases
    The following table provides information regarding the presentation of leases on the Consolidated Balance Sheets:
Amounts Recognized on TVA's Consolidated Balance Sheets
At September 30
(in millions)
20252024
Assets
  OperatingOperating lease assets, net of amortization$113 $149 
  FinanceFinance leases663 729 
Total lease assets$776 $878 
Liabilities
Current
  OperatingAccounts payable and accrued liabilities$46 $63 
  FinanceAccounts payable and accrued liabilities86 80 
Non-current
  OperatingOther long-term liabilities63 88 
  FinanceFinance lease liabilities640 700 
Total lease liabilities$835 $931 
    TVA's leases consist primarily of railcars, equipment, real estate/land, power generating facilities, and gas pipelines. TVA's leases have various terms and expiration dates remaining from less than one year to 21 years. The components of lease costs were as follows:
Lease Costs
For the years ended September 30
(in millions)
202520242023
Operating lease costs(1)
$73 $77 $69 
Variable lease costs(1)(5)
337 258 134 
Short-term lease costs(1)
15 10 18 
Finance lease costs
Amortization of lease assets(2)
91 79 57 
Interest on lease liabilities(3)(4)
46 37 43 
Total finance lease costs137 116 100 
     Total lease costs$562 $461 $321 

Notes
(1) Costs are included in Operating and maintenance expense, Fuel expense, Purchased power expense, and Tax equivalents expense on the Consolidated Statements of Operations.
(2) Expense is included in Depreciation and amortization expense on the Consolidated Statements of Operations.
(3) Expense is included in Interest expense on the Consolidated Statements of Operations.
(4) Certain finance leases receive regulatory accounting treatment and are reclassified to Fuel expense and Purchased power expense.
(5) Variable lease costs include costs related to variable payments that are based on energy production levels, which are allocated to expense based on the determination of lease and non-lease components associated with the underlying agreements.

    TVA's variable lease costs are primarily related to energy payments that are based on energy production levels. Payments under those agreements are solely based on the actual output over the lease term. Certain TVA lease agreements contain renewal options. Those renewal options that are reasonably certain to be exercised are included in the lease measurements.

The following table contains additional information with respect to cash and non-cash activities related to leases:
Amounts Recognized on TVA's Consolidated Statements of Cash Flows
For the years ended September 30
(in millions)
202520242023
Operating cash flows for operating leases$72 $78 $77 
Operating cash flows for finance leases46 37 43 
Financing cash flows for finance leases82 76 56 
Lease assets obtained in exchange for lease obligations (non-cash)
Operating leases$14 $115 $84 
Finance leases28 230 3 

TVA has certain finance leases under PPAs under which the present value of the minimum lease payments exceeds the fair value of the related lease asset at the date of measurement.  This resulted in an interest rate that was higher than TVA's incremental borrowing rate. The weighted average remaining lease terms in years and the weighted average discount rate for TVA's operating and finance leases were as follows:
Weighted Averages
At September 30
20252024
Weighted average remaining lease terms
Operating leases3 years4 years
   Finance leases(1)
8 years9 years
Weighted average discount rate(2)
Operating leases4.2%4.3%
Finance leases17.0%17.6%
Note
(1) One of TVA's finance leases includes an option period to extend, which TVA is reasonably certain to exercise.
(2) The discount rate is calculated using the rate implicit in a lease if it is readily determinable. If the rate used by the lessor is not readily determinable, TVA uses its incremental borrowing rate as permitted by accounting guidance. The incremental borrowing rate is influenced by TVA's credit rating and lease term and as such may differ for individual leases, embedded leases, or portfolios of leased assets.

    The following table presents maturities of lease liabilities and a reconciliation of the undiscounted cash flows to lease liabilities at September 30, 2025:
Future Minimum Lease Payments
Minimum payments outstanding at September 30, 2025
(in millions)
Operating leases
2026$50 
202735 
202819 
20294 
20302 
Thereafter6 
Minimum annual payments116 
Less: present value discount(7)
Operating present value of net minimum lease payments$109 
Finance leases
2026$144 
2027142 
2028137 
2029134 
2030133 
   Thereafter340 
Minimum annual payments1,030 
Less: amount representing interest(304)
Finance present value of net minimum lease payments$726 

TVA has entered into three PPAs with renewable resource providers for solar generation and rights to charge and discharge battery energy storage systems. The systems are considered a lease component in these agreements. These PPAs have terms of 15 - 20 years and are expected to commence between January 2026 and December 2028. Total capacity payments related to these batteries over the term of these PPAs are expected to total $862 million.
Lessee, Finance Leases . Leases
    The following table provides information regarding the presentation of leases on the Consolidated Balance Sheets:
Amounts Recognized on TVA's Consolidated Balance Sheets
At September 30
(in millions)
20252024
Assets
  OperatingOperating lease assets, net of amortization$113 $149 
  FinanceFinance leases663 729 
Total lease assets$776 $878 
Liabilities
Current
  OperatingAccounts payable and accrued liabilities$46 $63 
  FinanceAccounts payable and accrued liabilities86 80 
Non-current
  OperatingOther long-term liabilities63 88 
  FinanceFinance lease liabilities640 700 
Total lease liabilities$835 $931 
    TVA's leases consist primarily of railcars, equipment, real estate/land, power generating facilities, and gas pipelines. TVA's leases have various terms and expiration dates remaining from less than one year to 21 years. The components of lease costs were as follows:
Lease Costs
For the years ended September 30
(in millions)
202520242023
Operating lease costs(1)
$73 $77 $69 
Variable lease costs(1)(5)
337 258 134 
Short-term lease costs(1)
15 10 18 
Finance lease costs
Amortization of lease assets(2)
91 79 57 
Interest on lease liabilities(3)(4)
46 37 43 
Total finance lease costs137 116 100 
     Total lease costs$562 $461 $321 

Notes
(1) Costs are included in Operating and maintenance expense, Fuel expense, Purchased power expense, and Tax equivalents expense on the Consolidated Statements of Operations.
(2) Expense is included in Depreciation and amortization expense on the Consolidated Statements of Operations.
(3) Expense is included in Interest expense on the Consolidated Statements of Operations.
(4) Certain finance leases receive regulatory accounting treatment and are reclassified to Fuel expense and Purchased power expense.
(5) Variable lease costs include costs related to variable payments that are based on energy production levels, which are allocated to expense based on the determination of lease and non-lease components associated with the underlying agreements.

    TVA's variable lease costs are primarily related to energy payments that are based on energy production levels. Payments under those agreements are solely based on the actual output over the lease term. Certain TVA lease agreements contain renewal options. Those renewal options that are reasonably certain to be exercised are included in the lease measurements.

The following table contains additional information with respect to cash and non-cash activities related to leases:
Amounts Recognized on TVA's Consolidated Statements of Cash Flows
For the years ended September 30
(in millions)
202520242023
Operating cash flows for operating leases$72 $78 $77 
Operating cash flows for finance leases46 37 43 
Financing cash flows for finance leases82 76 56 
Lease assets obtained in exchange for lease obligations (non-cash)
Operating leases$14 $115 $84 
Finance leases28 230 3 

TVA has certain finance leases under PPAs under which the present value of the minimum lease payments exceeds the fair value of the related lease asset at the date of measurement.  This resulted in an interest rate that was higher than TVA's incremental borrowing rate. The weighted average remaining lease terms in years and the weighted average discount rate for TVA's operating and finance leases were as follows:
Weighted Averages
At September 30
20252024
Weighted average remaining lease terms
Operating leases3 years4 years
   Finance leases(1)
8 years9 years
Weighted average discount rate(2)
Operating leases4.2%4.3%
Finance leases17.0%17.6%
Note
(1) One of TVA's finance leases includes an option period to extend, which TVA is reasonably certain to exercise.
(2) The discount rate is calculated using the rate implicit in a lease if it is readily determinable. If the rate used by the lessor is not readily determinable, TVA uses its incremental borrowing rate as permitted by accounting guidance. The incremental borrowing rate is influenced by TVA's credit rating and lease term and as such may differ for individual leases, embedded leases, or portfolios of leased assets.

    The following table presents maturities of lease liabilities and a reconciliation of the undiscounted cash flows to lease liabilities at September 30, 2025:
Future Minimum Lease Payments
Minimum payments outstanding at September 30, 2025
(in millions)
Operating leases
2026$50 
202735 
202819 
20294 
20302 
Thereafter6 
Minimum annual payments116 
Less: present value discount(7)
Operating present value of net minimum lease payments$109 
Finance leases
2026$144 
2027142 
2028137 
2029134 
2030133 
   Thereafter340 
Minimum annual payments1,030 
Less: amount representing interest(304)
Finance present value of net minimum lease payments$726 

TVA has entered into three PPAs with renewable resource providers for solar generation and rights to charge and discharge battery energy storage systems. The systems are considered a lease component in these agreements. These PPAs have terms of 15 - 20 years and are expected to commence between January 2026 and December 2028. Total capacity payments related to these batteries over the term of these PPAs are expected to total $862 million.
v3.25.3
Research and Development
 12 Months Ended
Sep. 30, 2025
Research and Development [Abstract]  
Collaborative Arrangement Disclosure
22. Collaborative Arrangement

In 2023, TVA, Ontario Power Generation, BWRX TCA sp. z.o.o., and GE Vernova Hitachi Nuclear Energy ("GVH") entered into a multi-party collaborative arrangement to advance the global deployment of the GVH BWRX-300 small modular reactor. GVH is responsible for standard design development. Under the agreement, TVA will contribute up to $93 million for design costs incurred by GVH 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 Statements of Operations in the period incurred. TVA recorded $11 million and $41 million of expenses related to this agreement for the years ended September 30, 2025 and 2024, respectively. TVA also had a $6 million letter of credit posted under this arrangement at September 30, 2025.
v3.25.3
Restructuring and Related Activities
 12 Months Ended
Sep. 30, 2025
Restructuring and Related Activities [Abstract]  
Restructuring and Related Activities Disclosure Restructuring
TVA’s demand continues to grow, driving the need for significant future capital investment. TVA must continue to drive efficiencies and cost savings across the enterprise to provide affordable, reliable electricity, while funding the capital investment needed to meet growing demand. This effort has evolved into an Enterprise Transformation Program ("ETP") focused on improving financial health, enhancing asset performance, automating processes, optimizing third-party spend through supply chain, and making the workforce more efficient. As part of these efforts, certain employees are eligible for severance payments. These amounts are recognized in Operating and maintenance expense on TVA's Consolidated Statements of Operations in the period incurred. Severance costs that have been incurred but not paid are included in Accounts payable and accrued liabilities on TVA's Consolidated Balance Sheets. The organizational design efforts associated with the ETP were complete as of September 30, 2025; however, the ETP is ongoing as TVA executes the focus areas described above. The table below summarizes the activity related to severance costs:

Severance Cost Liability Activity
(in millions)
Severance cost liability at September 30, 2024$— 
Liabilities incurred during the period40 
Actual costs paid during the period(29)
Severance cost liability at September 30, 2025
$11 
v3.25.3
Segment Reporting
 12 Months Ended
Sep. 30, 2025
Segment Reporting [Abstract]  
Segment Reporting Disclosure Segment Reporting
TVA operates as a single reportable segment that includes the generation, transmission, and sale of electricity throughout the Tennessee Valley. Revenue is primarily derived from wholesale electricity sales to LPCs and directly served customers. TVA's Chief Executive Officer ("CEO") serves as the CODM. The CODM uses net income in the annual planning process and to monitor budget versus actual results on a monthly basis in assessing financial performance and in determining how to allocate resources.

The following table includes operating revenues, expenses, and net income as regularly provided to the CODM, which align directly to the amounts presented in TVA’s Consolidated Statements of Operations. As the segment measure used by the CODM is net income, no reconciliation is necessary.

For the years ended September 30
(in millions)
2025
2024(2)
2023(2)
Base Revenue$9,415 $8,725 $7,863 
Fuel Revenue4,068 3,398 4,025 
Other Revenue189191 166 
Total Operating Revenue13,672 12,314 12,054 
Fuel2,376 2,169 2,549 
Purchased Power2,106 1,581 1,633 
Operating and Maintenance3,717 3,641 3,372 
Depreciation and Amortization2,271 2,138 2,213 
Interest Expense1,196 1,066 1,056 
Tax Equivalents633 557 593 
Other Segment Items(1)
13 27 138 
Net Income$1,360 $1,135 $500 
Notes
(1) Other segment items include non-utility related miscellaneous income and expenses, pension and post-retirement benefit costs, and interest income.
(2) Prior period amounts have been reclassified to conform to the current period presentation resulting from the retrospective adoption of ASU 2023-07, Segment Reporting. Expanded segment disclosures were not required in the comparative periods presented because the company operated, and continues to operate, as a single reportable segment for which detailed segment expense disclosures were not previously required.

Segment asset information is not presented, as it is not regularly reviewed by the CODM. The CODM evaluates capital planning and resource allocation on a consolidated basis which is presented in TVA's Consolidated Balance Sheet.
Capital expenditures were $5.0 billion, $3.9 billion, and $3.0 billion for the years ended September 30, 2025, 2024, and 2023, respectively.
v3.25.3
Insider Trading Arrangements
 3 Months Ended
Sep. 30, 2025
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
v3.25.3
Cybersecurity Risk Management and Strategy Disclosure
 12 Months Ended
Sep. 30, 2025
Cybersecurity Risk Management, Strategy, and Governance [Line Items]  
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]
Risk Management

TVA’s cybersecurity risk management programs and processes exist under a written cybersecurity policy, which provides the foundation for TVA’s information security programs. Under the policy, TVA engages assessors, consultants, auditors, and other third parties. All TVA employees, contractors, grantees, other federal agencies, state and local governments, industry partners, and others who possess TVA information or who operate, use, or have access to TVA's information systems are made responsible for complying with TVA's cybersecurity policy and information security-related communications, plans, practices, procedures, and standards issued as part of the information security programs.

TVA’s cybersecurity risk management framework provides the structure for protecting against cybersecurity threats, including through promoting risk management efforts, situational awareness, and cyber risk modeling and simulations. Within this framework, TVA operates numerous programs under internal written policies and procedures, which are aimed at helping protect TVA’s information resources. These include a vulnerability management program to help address cybersecurity threats to TVA digital assets; a patch and remediation management program to help computer systems remain current with software patches or software updates; an offensive threat management program to emulate threat actor activities; a cybersecurity training program to help educate employees and contractors, including by providing scenarios designed to train the workforce on responding to cybersecurity incidents; implementation of standard terms and conditions where appropriate in TVA’s supply chain contracts to help mitigate TVA’s cybersecurity risk, including through requiring timely notice of vendor cybersecurity incidents and data impacts and compliance with laws, regulations, and TVA’s policies on cybersecurity; and a program to accomplish cybersecurity event detection alerting. These programs are based on principles from the National Institute of Standards and Technology and certain regulatory standards that are designed to protect against cybersecurity incidents, including the North
American Electric Reliability Corporation Critical Infrastructure Protection Standards and Nuclear Regulatory Commission cybersecurity standards, and are periodically assessed by third-party experts.

In the last three fiscal years, TVA has not experienced any material cybersecurity incidents. TVA is not currently aware of any potential cybersecurity threats, including as a result of any previous cybersecurity incidents, that may have materially affected or are reasonably likely to materially affect TVA, including its business strategy, results of operations, or financial condition; however, TVA cannot provide assurance that it will not be materially affected in the future by cybersecurity risks or any future material risks. For more information on TVA’s cybersecurity related risks, see Item 1A, Risk Factors – Cybersecurity and Information Technology Risks in this Annual Report.
Cybersecurity Risk Management Processes Integrated [Text Block] . Within this framework, TVA operates numerous programs under internal written policies and procedures, which are aimed at helping protect TVA’s information resources. These include a vulnerability management program to help address cybersecurity threats to TVA digital assets; a patch and remediation management program to help computer systems remain current with software patches or software updates; an offensive threat management program to emulate threat actor activities; a cybersecurity training program to help educate employees and contractors, including by providing scenarios designed to train the workforce on responding to cybersecurity incidents; implementation of standard terms and conditions where appropriate in TVA’s supply chain contracts to help mitigate TVA’s cybersecurity risk, including through requiring timely notice of vendor cybersecurity incidents and data impacts and compliance with laws, regulations, and TVA’s policies on cybersecurity; and a program to accomplish cybersecurity event detection alerting.
Cybersecurity Risk Management Third Party Engaged [Flag] true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag] true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag] false
Cybersecurity Risk Board of Directors Oversight [Text Block] The TVA Board is ultimately responsible for oversight of the identification, management, and mitigation of enterprise-wide risk, including cybersecurity risk, and receives reports from the Audit, Risk, and Cybersecurity Committee (“Audit Committee”).
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block] The Audit Committee is a standing committee of the TVA Board and advises the TVA Board on a variety of matters, including TVA’s processes for identifying, monitoring, and mitigating enterprise risk and reviewing and overseeing strategies for addressing TVA’s cybersecurity, data, and privacy policies and response protocols. The Audit Committee meets at least quarterly.
Cybersecurity Risk Role of Management [Text Block] TVA’s management of enterprise-wide risks with policy implications reported to the TVA Board or a designated TVA Board committee. The risk council oversees a subordinate committee that provides comprehensive risk oversight of TVA’s security, artificial intelligence, privacy, and technology risks consistent with TVA’s mission, strategic imperatives, and approved financial and operational plans.
Cybersecurity Risk Management Positions or Committees Responsible [Text Block] Reporting to the Audit Committee and the TVA Board is the risk council comprised of TVA’s top leaders and the Chief Risk Officer (“CRO”), which is responsible for the highest level of management oversight of risk at TVA. The risk council’s primary purpose is to oversee TVA’s management of enterprise-wide risks with policy implications reported to the TVA Board or a designated TVA Board committee. The risk council oversees a subordinate committee that provides comprehensive risk oversight of TVA’s security, artificial intelligence, privacy, and technology risks consistent with TVA’s mission, strategic imperatives, and approved financial and operational plans.
TVA’s governance, oversight, execution, and support activities include quarterly Enterprise Risk and Assurance updates to the Audit Committee, an annual alignment with TVA’s broader risk management framework and business planning initiatives, and tactical and intentional initiatives focused on reducing risk, increasing maturity, and helping ensure regulatory compliance and adherence. TVA engages in various audits in order to provide assurance of TVA’s effective management of cybersecurity risk and risk as a whole and is also subject to required external audits to ensure compliance with certain regulatory standards that are designed to protect against cybersecurity incidents.
TVA's current VP, Cybersecurity serves as Chief Information Security Officer ("CISO"). The current CISO is also designated as the Chief Artificial Intelligence Officer and the agency’s Federal Senior Intelligence Coordinator.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block] Starting in operational technology as part of nuclear generation, the current CISO has spent his career in public power in various North American Electric Reliability Corporation regions and has been in the industry for over 25 years. He has led Cybersecurity for over 10 years in the sector. He was previously the CISO of the New York Power Authority, and he has experience supporting all verticals of electric operations, from the perspectives of security, resiliency, and recovery. He is a Certified Information Security Manager and has previously held Chair and Co-chair roles in the industry, such as with the Electric Subsector Coordinating Council's Cyber Mutual Aid Committee. He seeks to focus on information sharing and building partnerships to enable understanding of emerging threats. The current CISO remains active in various security organizations and the broader industry. He has a degree in Computer Science and a Master of Business Administration.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block] TVA’s governance, oversight, execution, and support activities include quarterly Enterprise Risk and Assurance updates to the Audit Committee
v3.25.3
Summary of Significant Accounting Policies [Policy Text Block]
 12 Months Ended
Sep. 30, 2025
Accounting Policies [Abstract]  
General
General

The Tennessee Valley Authority ("TVA") is a corporate agency and instrumentality of the United States ("U.S.") that was created in 1933 by federal legislation in response to a proposal by President Franklin D. Roosevelt.  TVA was created to, among other things, improve navigation on the Tennessee River, reduce the damage from destructive flood waters within the Tennessee River system and downstream on the lower Ohio and Mississippi Rivers, further the economic development of TVA's service area in the southeastern U.S., and sell the electricity generated at the facilities TVA operates. Today, TVA operates the nation's largest public power system and supplies power in most of Tennessee, northern Alabama, northeastern Mississippi, and southwestern Kentucky and in portions of northern Georgia, western North Carolina, and southwestern Virginia to a population of approximately 10 million people.

    TVA also manages the Tennessee River, its tributaries, and certain shorelines to provide, among other things, year-round navigation, flood damage reduction, and affordable and reliable electricity. Consistent with these primary purposes, TVA also manages the river system and public lands to provide recreational opportunities, adequate water supply, improved water quality, cultural and natural resource protection, and economic development. TVA performs these management duties in cooperation with other federal and state agencies that have jurisdiction and authority over certain aspects of the river system. In addition, the TVA Board of Directors ("TVA Board") has established two councils — the Regional Resource Stewardship Council and the Regional Energy Resource Council — to advise TVA on its stewardship activities in the Tennessee Valley and its energy resource activities.

The power program has historically been separate and distinct from the stewardship programs.  It is required to be self-supporting from power revenues and proceeds from power financings, such as proceeds from the issuance of bonds, notes, or other evidences of indebtedness (collectively, "Bonds").  Although TVA does not currently receive Congressional appropriations, it is required to make annual payments to the United States Department of the Treasury ("U.S. Treasury") as a return on the government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment").  In the 1998
Energy and Water Development Appropriations Act, Congress directed TVA to fund essential stewardship activities related to its management of the Tennessee River system and nonpower or stewardship properties with power revenues in the event that there were insufficient appropriations or other available funds to pay for such activities in any fiscal year.  Congress has not provided any appropriations to TVA to fund such activities since 1999.  Consequently, during 2000, TVA began paying for essential stewardship activities primarily with power revenues, with the remainder funded with user fees and other forms of revenues derived in connection with those activities.  The activities related to stewardship properties do not meet the criteria of an operating segment under accounting principles generally accepted in the United States of America ("GAAP").  Accordingly, these assets and properties are included as part of the power program, TVA's only operating segment.

Power rates are established by the TVA Board as authorized by the Tennessee Valley Authority Act of 1933, as amended ("TVA Act").  The TVA Act requires TVA to charge rates for power that will produce gross revenues sufficient to provide funds for operation, maintenance, and administration of its power system; payments to states and counties in lieu of taxes ("tax equivalents"); debt service on outstanding indebtedness; payments to the U.S. Treasury in repayment of and as a return on the Power Program Appropriation Investment; and such additional margin as the TVA Board may consider desirable for investment in power system assets, retirement of outstanding Bonds in advance of maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected with TVA's power business.  TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment with the 2014 payment; therefore, this repayment obligation is no longer a component of rate setting. In setting TVA's rates, the TVA Board is charged by the TVA Act to have due regard for the primary objectives of the TVA Act, including the objective that power shall be sold at rates as low as are feasible.  Rates set by the TVA Board are not subject to review or approval by any state or other federal regulatory body.
Fiscal Year
Fiscal Year

TVA's fiscal year ends September 30.  Years (2025, 2024, etc.) refer to TVA's fiscal years unless they are preceded by "CY," in which case the references are to calendar years.
Cost-Based Regulation
Cost-Based Regulation

Since the TVA Board is authorized by the TVA Act to set rates for power sold to its customers, TVA is self-regulated. Additionally, TVA's regulated rates are designed to recover its costs.  Based on current projections, TVA believes that rates, set at levels that will recover TVA's costs, can be charged and collected.  As a result of these factors, TVA records certain assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for non-regulated entities.   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.  TVA assesses whether the regulatory assets are probable of future recovery by considering factors such as applicable regulatory changes, potential legislation, and changes in technology.  Based on these assessments, TVA believes the existing regulatory assets are probable of recovery.  This determination reflects the current regulatory and political environment and is subject to change in the future.  If future recovery of regulatory assets ceases to be probable, or TVA is no longer considered to be a regulated entity, then costs would be required to be written off.  All regulatory asset write offs would be required to be recognized in earnings in the period in which future recovery ceases to be probable or in which TVA is no longer considered to be a regulated entity.
Basis of Presentation
Basis of Presentation
    The accompanying consolidated 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 12 — Variable Interest Entities. Intercompany balances and transactions have been eliminated in consolidation.
Use of Estimates
Use of 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 consolidated financial statements.  Although the consolidated financial statements are prepared in conformity with GAAP, 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 considered 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.
Cash and Cash Equivalents and Restricted Cash and Investments
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. See Note 23 — Commitments and Contingencies — Legal Proceedings — Environmental Agreements.

    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
At September 30
(in millions)
 20252024
Cash and cash equivalents$1,576 $502 
Restricted cash and cash equivalents included in Other long-term assets21 21 
Total cash, cash equivalents, and restricted cash$1,597 $523 
TVA's balance of Cash and cash equivalents increased at September 30, 2025 due to the issuance of long-term bonds in the fourth quarter in anticipation of cash needed to pay bond maturities in November 2025.
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/or 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. As of September 30, 2025, TVA adopted the practical expedient in accordance with the accounting guidance for Current Expected Credit Losses, to assume that the current conditions as of the balance sheet date will remain unchanged for the remaining life of the asset when developing a reasonable and supportable forecast as part of estimating expected credit losses for trade receivables based on TVA's corporate credit department assessment of the financial condition of customers and the credit quality of the receivables.

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 $14 million and less than $1 million at September 30, 2025, and 2024, respectively, for trade accounts receivable.  At September 30, 2025, the allowance for uncollectible accounts included $14 million related to one local power company customer ("LPC"). Additionally, loans receivable of $86 million and $105 million at September 30, 2025 and 2024, respectively, are included in Accounts receivable, net and Other long-term assets for the current and long-term portions, respectively. Loans receivable are reported net of allowances for uncollectible accounts of $2 million at both September 30, 2025 and 2024.
Revenues
Revenues

TVA recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount to which the entity expects to be entitled in exchange for those goods or services. For the generation and transmission of electricity, this is generally at the time the power is delivered to a metered customer delivery point for the customer's consumption or distribution. As a result, revenues from power sales are recorded as electricity is delivered to customers. In addition to power sales invoiced and recorded during the month, TVA accrues estimated unbilled revenues for power sales provided to five customers whose billing date occurs prior to the end of the month.  Exchange power sales are presented in the accompanying Consolidated Statements of Operations as a component of sales of electricity. Exchange power sales are sales of excess power after meeting TVA native load and directly served requirements.  Native load refers to the customers on whose behalf a company, by statute, franchise, regulatory requirement, or contract, has undertaken an obligation to serve. TVA
engages in other arrangements in addition to power sales. Certain other revenue from activities related to TVA's overall mission is recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income, net.
Inventories
Inventories

Certain Fuel, Materials, and Supplies.  Materials and supplies inventories are valued using an average unit cost method. A new average cost is computed after each inventory purchase transaction, and inventory issuances are priced at the latest moving weighted average unit cost. Coal, fuel oil, and natural gas inventories are valued using an average cost method. A new weighted average cost is computed monthly, and monthly issues are priced accordingly.

Renewable Energy Certificates. TVA accounts for Renewable Energy Certificates ("RECs") using the specific identification cost method. RECs that are acquired through power purchases are recorded as inventory and charged to purchased power expense when the RECs are subsequently used or sold. TVA assigns a value to the RECs at the inception of the power purchase arrangement using a relative standalone selling price approach. RECs created through TVA-owned asset generation are recorded at zero cost.

Emission Allowances.  TVA accounts for emission allowances using the specific identification cost method. Allowances that are acquired through third party purchases are recorded as inventory at cost and charged to operating expense based on tons emitted during the respective compliance periods.  

Allowance for Inventory Obsolescence.  TVA reviews materials and supplies inventories by category and usage on a periodic basis.  Each category is assigned a probability of becoming obsolete based on the type of material and historical usage data.  TVA has a fleet-wide inventory management policy for each generation type. Based on the estimated value of the inventory, TVA adjusts its allowance for inventory obsolescence.
Property, Plant, and Equipment, and Depreciation
Property, Plant, and Equipment, and Depreciation

    Property, Plant, and Equipment. Additions to plant are recorded at cost, which includes direct and indirect costs.  The cost of current repairs and minor replacements is charged to operating expense. When property, plant, and equipment is retired, accumulated depreciation is charged for the original cost of the assets. Gains or losses are only recognized upon the sale of land or an entire operating unit. TVA capitalizes certain costs incurred in connection with developing or obtaining internal-use software. Capitalized software costs are included in Property, plant, and equipment on the Consolidated Balance Sheets and are generally amortized over seven years.  

Nuclear Fuel. Nuclear fuel, which is included in Property, plant, and equipment, is valued using the average cost method for raw materials and the specific identification method for nuclear fuel in a reactor.  Amortization of nuclear fuel in a reactor is calculated on a units-of-production basis and is included in fuel expense.

TVA and the Department of Energy ("DOE") are parties to an interagency agreement (referred to as the Down-blend Offering for Tritium), under which surplus DOE highly enriched uranium and other uranium is processed by third-party contractors into low-enriched uranium, which is then fabricated into nuclear fuel for use in TVA's nuclear power plants.  Production of the low-enriched uranium began in 2019 and will continue through the end of the interagency agreement term in September 2027. After that date, any remaining uranium in storage will be managed to ensure that the uranium is unencumbered by policy restrictions, so that it can be used in connection with the production of tritium. Under the terms of the interagency agreement, the DOE will reimburse TVA for a portion of the costs of converting the highly enriched uranium to low-enriched uranium. Since 2019, TVA has received $334 million in reimbursements from the DOE, which is recorded as a reduction in nuclear fuel inventory costs. At September 30, 2025, TVA recorded $6 million in Accounts receivable, net related to this agreement.

    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 in 2022.

Depreciation expense for the years ended September 30, 2025, 2024, and 2023 was $1.9 billion, $1.8 billion, and $1.9 billion, respectively. Depreciation expense expressed as a percentage of the average annual depreciable completed plant was 3.04 percent for 2025, 2.92 percent for 2024, and 3.14 percent for 2023.  Average depreciation rates by asset class are as follows:
Property, Plant, and Equipment Depreciation Rates
At September 30
(percent)
202520242023
Asset Class
Nuclear2.71 2.71 2.73 
Coal-fired(1)
4.82 4.13 4.98 
Hydroelectric1.82 1.83 1.82 
Gas and oil-fired3.16 3.31 3.17 
Transmission1.55 1.52 1.52 
Other5.22 4.98 4.43 
Note
(1) The rates include the acceleration of depreciation related to retiring certain coal-fired units and potentially retiring the remainder of the coal-fired fleet by 2035. See Note 8 — Plant Closures.

Reacquired Rights. TVA previously entered into leasing transactions to obtain third-party financing for 24 peaking CTs as well as certain qualified technological equipment and software. All of the lease proceeds were accounted for as financing obligations due to TVA’s continuing involvement with the combustion turbine facilities and the qualified technological equipment and software during the leaseback term. These financial obligations were paid off, and TVA acquired the residual leasehold interests for all of this equipment and recorded the cash consideration as reacquired rights, which is an intangible asset included in property, plant, and equipment on the Consolidated Balance Sheet. At September 30, 2025 and 2024, property, plant, and equipment includes intangible reacquired rights, net of amortization, of $301 million and $312 million, respectively. Reacquired rights are amortized over the estimated useful lives of the underlying CTs which range from 30 to 35 years. Amortization expense was $11 million, $11 million, and $10 million for the years ended September 30, 2025, 2024, and 2023, respectively, and accumulated amortization at September 30, 2025 and 2024 totaled $74 million and $63 million, respectively. At September 30, 2025, the estimated aggregate amortization expense for each of the next five years and thereafter is shown below:

 20262027202820292030Thereafter
Reacquired Rights$11 $12 $11 $11 $12 $244 
Impairment of Assets.  TVA evaluates long-lived assets for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.  For long-lived assets, TVA bases its evaluation on impairment indicators such as the nature of the assets, the future economic benefit of the assets, any historical or future profitability measurements, regulatory approval and ability to set rates at levels that allow for recoverability of the assets, and other external market conditions or factors that may be present.  If such impairment indicators are present or other factors exist that indicate that the carrying amount of an asset may not be recoverable, TVA determines whether an impairment has occurred based on an estimate of undiscounted cash flows attributable to the asset as compared with the carrying value of the asset.  If an impairment has occurred, the amount of the impairment recognized is measured as the excess of the asset's carrying value over its fair value.  Additionally, TVA regularly evaluates construction projects.  If the project is canceled or deemed to have no future economic benefit, the project is written off as an asset impairment or, upon TVA Board approval, reclassified as a regulatory asset and amortized over the Board-approved period. See Note 8 — Plant Closures.
Lessee, Leases
Leases

    TVA recognizes a lease asset and lease liability for leases with terms of greater than 12 months. Lease assets represent TVA's right to use an underlying asset for the lease term, and lease liabilities represent TVA's obligation to make lease payments arising from the lease, both of which are recognized based on the present value of the future minimum lease payments over the lease term at the commencement date.  TVA has certain lease agreements that include variable lease payments that are based on energy production levels. These variable lease payments are not included in the measurement of the lease assets or lease liabilities but are recognized in the period in which the expenses are incurred.

    While not specifically structured as leases, certain power purchase agreements ("PPAs") are deemed to contain a lease of the underlying generating units when the terms convey the right to control the use of the assets. Amounts recorded for these leases are generally based on the amount of the scheduled capacity payments due over the remaining terms of the PPAs, the
terms of which vary. The total lease obligations included in Accounts payable and accrued liabilities, Other long-term liabilities, and Finance lease liabilities related to these agreements were $509 million and $75 million for finance and operating leases, respectively, at September 30, 2025. The total lease obligations included in Accounts payable and accrued liabilities, Other long-term liabilities, and Finance lease liabilities related to these agreements were $550 million and $121 million for finance and operating leases, respectively, at September 30, 2024.

    TVA has agreements with lease and non-lease components and has elected to separate lease and non-lease components. Consideration is allocated to lease and non-lease components generally based on relative standalone price basis. Variable lease costs included in the agreements are allocated based on the determination of lease and non-lease components.

    TVA has lease agreements which include options for renewal and early termination. The intent to renew a lease varies depending on the lease type and asset. Renewal options that are reasonably certain to be exercised are included in the lease measurements. The decision to terminate a lease early is dependent on various economic factors. No termination options have been included in TVA's lease measurements.
    
    Leases with an initial term of 12 months or less, which do not include an option to extend the initial term of the lease to greater than 12 months that TVA is reasonably certain to exercise, are not recorded on the Consolidated Balance Sheets at September 30, 2025.
    Operating leases are recognized on a straight-line basis over the term of the lease agreement. Rent expense associated with short-term leases and variable leases is recorded in Operating and maintenance expense, Fuel expense, or Purchased power expense on the Consolidated Statements of Operations. Expenses associated with finance leases result in the separate presentation of interest expense on the lease liability and amortization expense of the related lease asset on the Consolidated Statements of Operations.
Decommissioning Costs
Decommissioning Costs

    TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets.  These obligations relate to fossil fuel-fired generating plants, nuclear generating plants, hydroelectric generating plants/dams, transmission structures, and other property-related assets.  Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site restoration. Revisions to the forecasted costs of decommissioning activities are made whenever factors indicate that the timing or amounts of estimated cash flows have changed materially. Studies are updated for both nuclear and non-nuclear decommissioning costs at least every five years.  Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset.  See Note 11 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs and Note 14 — Asset Retirement Obligations.
Investment Funds
Investment Funds

    Investment funds consist primarily of trust funds designated to fund decommissioning requirements (see Note 23 — Commitments and Contingencies — Contingencies — Decommissioning Costs), the Supplemental Executive Retirement Plan ("SERP") (see Note 21 — Benefit Plans — Overview of Plans and Benefits — Supplemental Executive Retirement Plan), the Deferred Compensation Plan ("DCP"), and the Restoration Plan ("RP"). The Nuclear Decommissioning Trust ("NDT") holds funds primarily for the ultimate decommissioning of TVA's nuclear power plants. The Asset Retirement Trust ("ART") holds funds primarily for the costs related to the future closure and retirement of TVA's other long-lived assets. 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 funds are all classified as trading.
Research and Development Costs
Research and Development Costs

Research and development costs are expensed when incurred.  TVA's research programs include those related to power delivery technologies, emerging technologies, technologies related to generation (fossil fuel, nuclear, and hydroelectric), and environmental technologies.
Tax Equivalents
Tax Equivalents

TVA is not subject to federal income taxation. In addition, neither TVA nor its property, franchises, or income is subject to taxation by states or their subdivisions. The TVA Act requires TVA to make payments to states and counties in which TVA conducts its power operations and in which TVA has acquired power properties previously subject to state and local taxation.   The total amount of these payments is five percent of gross revenues from sales of power during the preceding year, excluding sales or deliveries to other federal agencies and off-system sales with other utilities, with a provision for minimum payments under certain circumstances. TVA calculates tax equivalent expense by subtracting the prior year fuel cost-related tax equivalent regulatory asset or liability from the payments made to the states and counties during the current year and adding back the current year fuel cost-related tax equivalent regulatory asset or liability. Fuel cost-related tax equivalent expense is recognized in the same accounting period in which the fuel cost-related revenue is recognized.
Maintenance Costs
Maintenance Costs
TVA records maintenance costs and repairs related to its property, plant, and equipment on the Consolidated Statements of Operations as they are incurred except for the recording of certain regulatory assets for retirement and removal costs.
Pre-Commercial Plant Operations
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 ("CT") 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 year ended September 30, 2024. TVA also capitalized related fuel costs for this project of $3 million for the year ended September 30, 2024. Pre-commercial plant operations began on Johnsonville Aeroderivative CT Units 21-30 during 2025. Units 21-25 and 27-30 became operational on May 6, 2025, and Unit 26 became operational on August 20, 2025. Estimated revenue of $4 million related to this project was capitalized to offset project costs for the year ended September 30, 2025. TVA also capitalized related fuel costs for this project of $7 million for the year ended September 30, 2025.
v3.25.3
Deferred Costs, Capitalized, Prepaid, and Other Assets (Policies)
 12 Months Ended
Sep. 30, 2025
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 16 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Contract Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.
v3.25.3
Deferred Costs, Capitalized, Prepaid, and Other Assets (Policies)
 12 Months Ended
Sep. 30, 2025
Assets, Noncurrent [Abstract]  
Financing Receivable
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 September 30, 2025 and 2024, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $3 million and $21 million, respectively. Loans receivables are reported net of allowances for uncollectible accounts. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts..
Transfers and Servicing of Financial Assets, Transfers of Financial Assets, Financings, Policy
EnergyRight® Receivables. In association with the EnergyRight® program, TVA's 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 both September 30, 2025 and 2024, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was $12 million. See Note 13 — Other Long-Term Liabilities for information regarding the associated financing obligation.
Credit Loss, Financial Instrument
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
At September 30
(in millions)
20252024
EnergyRight® loan reserve
$1 $1 
Economic development loan specific loan reserve1 1 
Total allowance for loan losses$2 $2 
Service Agreements
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 September 30, 2025 and 2024, prepayments of $16 million and $7 million, respectively, were recorded in Other current assets.
Commodity contract derivative asset 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 16 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Contract Derivatives and — Commodity Derivatives under the FHP for a discussion of TVA's commodity contract derivatives.
Goodwill and Intangible Assets, Intangible Assets, Policy
Cloud Assets. TVA has capitalized the implementation costs of hosting arrangements that are considered service contracts as cloud assets. The cloud assets are amortized over the non-cancellable terms of the hosting arrangement, including renewal periods that are reasonably certain to be exercised. The current and long-term portions of the cloud assets are reported in Other current assets and Other long-term assets, respectively, on TVA’s Consolidated Balance Sheets. Amortization of the cloud asset is recognized in Operating and maintenance expense, consistent with the classification of the related hosting fees. At September 30, 2025, and September 30, 2024, the carrying amount of the cloud assets reported in Other current assets was $3 million and $13 million, respectively. For the years ended September 30, 2025, 2024, and 2023, TVA amortized $14 million, $15 million, and $7 million, respectively, as Operating and maintenance expense.
v3.25.3
Variable Interest Entities (Policies)
 12 Months Ended
Sep. 30, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Summary of Impact of VIEs on Consolidated Balance Sheets The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, SCCG, JACTG, and JHLLC as of September 30, 2025 and 2024, as reflected on the Consolidated Balance Sheets, are as follows:
Summary of Impact of VIEs on Consolidated Balance Sheets
At September 30
(in millions)
 20252024
Current liabilities 
Accrued interest$29 $9 
Accounts payable and accrued liabilities1 1 
Current maturities of long-term debt of variable interest entities49 37 
Total current liabilities
79 47 
Other liabilities
Other long-term liabilities14 16 
Long-term debt, net
Long-term debt of variable interest entities, net1,632 897 
Total liabilities$1,725 $960 
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.
v3.25.3
Asset Retirement Obligations Asset Retirement Obligations (Policies)
 12 Months Ended
Sep. 30, 2025
Asset Retirement Obligation Disclosure [Abstract]  
Asset Retirement Obligations, Policy
Decommissioning Costs

    TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets.  These obligations relate to fossil fuel-fired generating plants, nuclear generating plants, hydroelectric generating plants/dams, transmission structures, and other property-related assets.  Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site restoration. Revisions to the forecasted costs of decommissioning activities are made whenever factors indicate that the timing or amounts of estimated cash flows have changed materially. Studies are updated for both nuclear and non-nuclear decommissioning costs at least every five years.  Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset.  See Note 11 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs and Note 14 — Asset Retirement Obligations.
v3.25.3
Benefit Plans Benefit Plans (Policies)
 12 Months Ended
Sep. 30, 2025
Retirement Benefits [Abstract]  
Benefit Plans
Accounting Mechanisms

Regulatory Accounting.  TVA has classified all amounts related to unrecognized prior service costs/(credits), net actuarial gains or losses, and the funded status as regulatory assets or liabilities as such amounts are probable of collection in future rates. Additionally, TVA recognizes pension costs as regulatory assets or regulatory liabilities to the extent that the amount calculated under U.S. GAAP as pension expense differs from the amount TVA contributes to the pension plan as pension plan contributions. As a result of plan design changes, future contributions are expected to exceed the expense calculated under U.S. GAAP. Accordingly, TVA discontinued this regulatory accounting practice as all such deferred costs were recovered as of September 30, 2023.

Cost Method. TVA uses the projected unit credit cost method to determine the service cost and the projected benefit obligation for retirement, termination, and ancillary benefits.  Under this method, a "projected accrued benefit" is calculated at the beginning of the year and at the end of the year for each benefit that may be payable in the future.  The "projected accrued benefit" is based on the plan's accrual formula and upon service at the beginning or end of the year, but it uses final average compensation, social security benefits, and other relevant factors projected to the age at which the employee is assumed to leave active service.  The projected benefit obligation is the actuarial present value of the "projected accrued benefits" at the beginning of the year for employed participants and is the actuarial present value of all benefits for other participants.  The service cost is the actuarial present value of the difference between the "projected accrued benefits" at the beginning and end of the year.

Amortization of Net Gain or Loss.  TVA utilizes the corridor approach for gain/loss amortization.  Differences between actuarial assumptions and actual plan results are deferred and amortized into periodic cost only when the accumulated differences exceed 10 percent of the greater of the projected benefit obligation or the market-related value of plan assets.  If necessary, the excess is amortized over the average future expected working lifetime of participants expected to receive benefits, which is approximately 10 years for the pension plan and 15 years for the post-retirement plans.

Amortization of Prior Service Cost/(Credit). Amortization of net prior service cost/(credit) resulting from a plan change is included as a component of period expense in the year first recognized and every year thereafter until it is fully amortized.  The increase or decrease in the benefit obligation due to the plan change is amortized over the average remaining service period of participating employees expected to receive benefits under the plan. The pension and post-retirement plans currently have prior service costs/(credits) from plan changes made in 2016 and 2018, with remaining amortization periods ranging from two to four years. However, when a plan change reduces the benefit obligation, existing positive prior service costs are reduced or eliminated starting with the earliest established before a new prior service credit base is established.

Asset Method.  TVA's asset method calculates a market-related value of assets ("MRVA") that recognizes realized and unrealized investment gains and losses over a three-year smoothing period to decrease the volatility of annual net periodic pension benefit costs. The MRVA is used to determine the expected return on plan assets, a component of net periodic pension benefit cost. The difference in the expected return on the MRVA and the actual return on the fair value on plan assets is recognized as an actuarial (gain)/loss in the pension benefit obligation at September 30. However, the MRVA has no impact on the fair value of plan assets measured at September 30.
v3.25.3
Revenue (Policies)
 12 Months Ended
Sep. 30, 2025
Revenue from Contract with Customer [Abstract]  
Revenues
Revenues

TVA recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount to which the entity expects to be entitled in exchange for those goods or services. For the generation and transmission of electricity, this is generally at the time the power is delivered to a metered customer delivery point for the customer's consumption or distribution. As a result, revenues from power sales are recorded as electricity is delivered to customers. In addition to power sales invoiced and recorded during the month, TVA accrues estimated unbilled revenues for power sales provided to five customers whose billing date occurs prior to the end of the month.  Exchange power sales are presented in the accompanying Consolidated Statements of Operations as a component of sales of electricity. Exchange power sales are sales of excess power after meeting TVA native load and directly served requirements.  Native load refers to the customers on whose behalf a company, by statute, franchise, regulatory requirement, or contract, has undertaken an obligation to serve. TVA
engages in other arrangements in addition to power sales. Certain other revenue from activities related to TVA's overall mission is recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income, net.
v3.25.3
Plant Closures (Policies)
 12 Months Ended
Sep. 30, 2025
Plant Closure [Abstract]  
Plant Retirement and Abandonment, Policy [Policy Text Block]
Background

TVA must continuously evaluate all generating assets to ensure an optimal energy portfolio that provides safe and reliable power while maintaining flexibility and fiscal responsibility to the people of the Tennessee Valley. In January 2023, TVA issued its Record of Decision to retire two coal-fired units at Cumberland Fossil Plant ("Cumberland") by the end of CY 2026 and CY 2028. In April 2024, TVA issued its Record of Decision to retire the nine coal-fired units at Kingston Fossil Plant ("Kingston") by CY 2027. TVA is evaluating the impact of retiring the balance of the coal-fired fleet by 2035, and that evaluation includes
environmental reviews and TVA Board approval. TVA is also reviewing how recent executive orders, the evolving regulatory environment, and overall system performance are impacting the operation of its coal-fired fleet. An evaluation of the continued operation of coal-fired units is being conducted and will consider material condition, plant performance, system flexibility needs, environmental requirements, grid support, and other factors.

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. 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. The cumulative impact approximates $176 million of additional depreciation since January 2023, related to this decision. In addition, TVA's decision to retire the nine units at Kingston is estimated to result in approximately $9 million of additional depreciation quarterly, which does not include any potential impact from additions or retirements to net completed plant. The cumulative impact approximates $54 million of additional depreciation since April 2024 related to this decision.

TVA also recognized $15 million, $15 million, and $14 million in Operating and maintenance expense related to additional inventory reserves for the coal-fired fleet, including Kingston, Cumberland, and Bull Run Fossil Plant, for the years ended September 30, 2025, 2024, and 2023, respectively.
v3.25.3
Summary of Significant Accounting Policies [Table Text Block]
 12 Months Ended
Sep. 30, 2025
Accounting Policies [Abstract]  
Property, Plant, and Equipment Depreciation Rates Average depreciation rates by asset class are as follows:
Property, Plant, and Equipment Depreciation Rates
At September 30
(percent)
202520242023
Asset Class
Nuclear2.71 2.71 2.73 
Coal-fired(1)
4.82 4.13 4.98 
Hydroelectric1.82 1.83 1.82 
Gas and oil-fired3.16 3.31 3.17 
Transmission1.55 1.52 1.52 
Other5.22 4.98 4.43 
Schedule of Cash and Cash Equivalents 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
At September 30
(in millions)
 20252024
Cash and cash equivalents$1,576 $502 
Restricted cash and cash equivalents included in Other long-term assets21 21 
Total cash, cash equivalents, and restricted cash$1,597 $523 
v3.25.3
Accounts Receivable, Net Accounts Receivable, Net (Tables)
 12 Months Ended
Sep. 30, 2025
Accounts Receivable, after Allowance for Credit Loss [Abstract]  
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
At September 30
(in millions)
 20252024
Power receivables$1,908 $1,683 
Other receivables225 118 
Allowance for uncollectible accounts(1) (2)
(14)— 
Accounts receivable, net$2,119 $1,801 
Note
(1) 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, among other considerations. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts. At September 30, 2025, the allowance for uncollectible accounts included $14 million related to one LPC customer.
(2) The allowance for uncollectible accounts was less than $1 million at September 30, 2024.
v3.25.3
Inventories, Net Inventories, Net (Tables)
 12 Months Ended
Sep. 30, 2025
Inventory, Net [Abstract]  
Inventories, Net
The table below summarizes the types and amounts of TVA's inventories:
Inventories, Net 
At September 30
(in millions)
 20252024
Materials and supplies inventory$986 $931 
Fuel inventory278 286 
Renewable energy certificates/emissions allowance inventory, net12 11 
Allowance for inventory obsolescence(83)(73)
Inventories, net$1,193 $1,155 
v3.25.3
Deferred Costs, Capitalized, Prepaid, and Other Assets (Tables)
 12 Months Ended
Sep. 30, 2025
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]  
Schedule of Other Current Assets
Other current assets consisted of the following:
Other Current Assets 
At September 30
(in millions)
 2025
2024(1)
Inventory work-in-progress$69 $41 
Prepaid software maintenance25 22 
Prepaid insurance16 19 
Current portion of prepaid long-term service agreements16 7 
Commodity contract derivative assets14 5 
Prepaid dues & fees7 6 
Cloud assets3 13 
Other12 7 
Other current assets$162 $120 
Note
(1) At September 30, 2024, $6 million previously classified as Other (a component of Other current assets) has been reclassified to Prepaid dues & fees (a component of Other current assets) to conform to current year presentation.
v3.25.3
Net Completed Plant Net Completed Plant (Tables)
 12 Months Ended
Sep. 30, 2025
Property, Plant and Equipment, Net, by Type [Abstract]  
Net Completed Plant
Net completed plant consisted of the following:
Net Completed Plant
At September 30
(in millions)
 20252024
 CostAccumulated Depreciation 
Net		CostAccumulated DepreciationNet
Nuclear$27,091 $14,682 $12,409 $26,800 $14,149 $12,651 
Coal-fired(1)
19,029 15,760 3,269 20,177 16,635 3,542 
Gas, oil-fired, and other production7,746 2,274 5,472 7,051 2,112 4,939 
Transmission10,323 3,542 6,781 9,964 3,450 6,514 
Hydroelectric4,391 1,352 3,039 4,307 1,288 3,019 
Other electrical plant2,068 678 1,390 1,763 737 1,026 
Multipurpose dams900 419 481 900 413 487 
Other stewardship26 9 17 27 9 18 
Total$71,574 $38,716 $32,858 $70,989 $38,793 $32,196 
Note
(1) TVA recognized accelerated depreciation as a result of the decision to idle or retire certain units and the potential retirement of the remainder of the coal-fired fleet by 2035. See Note 8 — Plant Closures.
v3.25.3
Other Long-Term Assets (Tables)
 12 Months Ended
Sep. 30, 2025
Assets, Noncurrent [Abstract]  
Other Long-Term Assets
The table below summarizes the types and amounts of TVA's other long-term assets:
Other Long-Term Assets 
At September 30
(in millions)
 20252024
Cloud assets$114 $35 
Prepaid long-term service agreements89 62 
Loans and other long-term receivables, net83 84 
Prepaid capital assets81 29 
EnergyRight® receivables, net
45 44 
Commodity contract derivative assets10 2 
Other84 88 
Total other long-term assets$506 $344 
v3.25.3
Regulatory Assets and Liabilities Regulatory Assets and Liabilities (Tables)
 12 Months Ended
Sep. 30, 2025
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 
At September 30
(in millions)
 20252024
Current regulatory assets 
Unrealized losses on commodity contract derivatives$59 $102 
Unrealized losses on interest rate derivatives57 54 
Fuel cost adjustment receivable— 35 
Other current regulatory assets11 — 
Total current regulatory assets127 191 
Non-current regulatory assets  
Non-nuclear decommissioning costs5,563 6,187 
Retirement benefit plans deferred costs1,531 1,979 
Unrealized losses on interest rate derivatives316 447 
Environmental compliance and remediation costs308 215 
Nuclear decommissioning costs149 362 
Unrealized losses on commodity contract derivatives12 64 
Other non-current regulatory assets168 154 
Total non-current regulatory assets8,047 9,408 
Total regulatory assets$8,174 $9,599 
Current regulatory liabilities  
Fuel cost adjustment tax equivalents$203 $169 
Unrealized gains on commodity contract derivatives14 5 
Fuel cost adjustment payable11 — 
Total current regulatory liabilities228 174 
Non-current regulatory liabilities  
Retirement benefit plans deferred credits131 81 
Unrealized gains on commodity contract derivatives10 2 
Total non-current regulatory liabilities141 83 
Total regulatory liabilities$369 $257 
v3.25.3
Asset Retirement Obligations Asset Retirement Obligations (Tables)
 12 Months Ended
Sep. 30, 2025
Asset Retirement Obligation Disclosure [Abstract]  
Asset Retirement Obligation Activity
Asset Retirement Obligation Activity
(in millions)
 NuclearNon-NuclearTotal
Balance at September 30, 2023$3,808 $3,681 $7,489 
Settlements(4)(253)(257)
Revisions in estimate (non-cash)(160)292 132 
Additional obligations (non-cash)— 3,136 3,136 
Accretion (recorded as regulatory asset)170 136 306 
Balance at September 30, 20243,814 6,992 10,806 
(1)
Settlements(15)(255)(270)
Revisions in estimate (non-cash)2 (563)(561)
Accretion (recorded as regulatory asset)175 264 439 
Balance at September 30, 2025$3,976 $6,438 $10,414 
(1)
Note
(1) Includes $313 million and $283 million at September 30, 2025 and 2024, respectively, in Current liabilities.
v3.25.3
Other Long-Term Liabilities Other Long-Term Liabilities (Tables)
 12 Months Ended
Sep. 30, 2025
Other Liabilities, Noncurrent [Abstract]  
Other Long-Term Liabilities
Other long-term liabilities consist primarily of liabilities related to certain derivative agreements as well as liabilities related to environmental compliance and remediation and long-term project cost accruals. The table below summarizes the types and amounts of Other long-term liabilities:
Other Long-Term Liabilities
At September 30
(in millions)
 2025
2024(1)
Interest rate swap liabilities$643 $792 
Environmental compliance and remediation costs274 226 
Long-term project cost accruals204 140 
Currency swap liabilities108 109 
Operating lease liabilities63 88 
Advances for construction61 55 
Long-term deferred compensation54 50 
EnergyRight® financing obligation
53 52 
Long-term deferred revenue39 48 
Accrued long-term service agreements25 7 
Commodity contract derivative liabilities12 64 
Other70 81 
Total other long-term liabilities$1,606 $1,712 
Note
(1) At September 30, 2024, $21 million previously classified as Other (a component of Other long-term liabilities) has been reclassified to Environmental compliance and remediation costs ($14 million) and Accrued long-term service agreements ($7 million).
v3.25.3
Debt and Other Obligations Debt and Other Obligations (Tables)
 12 Months Ended
Sep. 30, 2025
Debt and Other Obligations [Abstract]  
Schedule of short-term borrowings The following table provides information regarding TVA's short-term borrowings:
Short-Term Borrowings
At September 30
 20252024
Gross amount outstanding - discount notes (in millions)$— $1,168 
Weighted average interest rate - discount notes— %4.76 %
Debt Securities Activity
The table below summarizes the long-term debt securities activity for the years ended September 30, 2025 and 2024.
Debt Securities Activity
For the years ended September 30
(in millions)
396720252024
Issues
Variable interest entities$800 $— 
2024 Series A(1)
— 1,000 
2025 Series A(2)
1,250 — 
2025 Series B(3)
1,500 — 
2025 Series C(4)
1,250 — 
Discount on debt issues(33)(9)
Total$4,767 $991 
Redemptions/Maturities(5)
 
2009 Series B$22 $22 
2014 Series A— 1,000 
2020 Series A1,000 — 
Total redemptions/maturities of power bonds1,022 1,022 
Debt of variable interest entities41 35 
Total redemptions/maturities of debt$1,063 $1,057 
Notes
(1) The 2024 Series A Bonds were issued at 99.109 percent of par.
(2) The 2025 Series A Bonds were issued at 98.517 percent of par.
(3) The 2025 Series B Bonds were issued at 99.360 percent of par.
(4) The 2025 Series C Bonds were issued at 99.593 percent of par.
(5) All redemptions were at 100 percent of par.
Debt Outstanding Total debt outstanding at September 30, 2025 and 2024, consisted of the following: 
Short-Term Debt
At September 30
(in millions)
 
CUSIP or Other Identifier
 
Maturity
 
Coupon Rate		20252024
Short-term debt, net of discounts$— $1,167 
Current maturities of long-term debt of variable interest entities49 37 
Current maturities of power bonds issued at par
880591EW85/15/20250.750%— 1,000 
880591CJ9(1)
11/1/20256.750%1,350 — 
880591EF512/15/20253.770%— 1 
880591EF56/15/20263.770%20 21 
Total current maturities of power bonds issued at par  1,370 1,022 
Total current debt outstanding, net  $1,419 $2,226 
Notes
(1) On November 1, 2025, TVA redeemed a $1.4 billion power bond due to maturity. TVA's next significant power bond maturity is $1.0 billion in February 2027.
Long-Term Debt
At September 30
(in millions)
 
CUSIP or Other Identifier
 
Maturity
Coupon
Rate		2025 Par2024 ParStock Exchange Listings
880591CJ911/1/20256.750%$— $1,350 New York, Hong Kong, Luxembourg, Singapore
880591EU22/1/20272.875%1,000 1,000 New York
880591EZ13/15/20283.875%1,000 1,000 New York
880591300(1)
6/1/20282.134%256 256 New York
880591409(1)
5/1/20292.216%208 208 New York
880591DM15/1/20307.125%1,000 1,000 New York, Luxembourg
880591FE78/1/20303.875%1,250 — New York
880591EX69/15/20311.500%500 500 New York
880591DP46/7/20326.587%
(2)
337 
(3)
335 
(3)
New York, Luxembourg
880591DV17/15/20334.700%472 472 New York, Luxembourg
880591EF56/15/20343.770%96 116 None
880591FB38/1/20344.375%1,000 1,000 New York
880591FD95/15/20354.875%1,500 — New York
880591DX76/15/20354.650%436 436 New York
880591CK64/1/20365.980%121 121 New York
880591CS94/1/20365.880%1,500 1,500 New York
880591CP51/15/20386.150%1,000 1,000 New York
880591ED06/15/20385.500%500 500 New York
880591EH19/15/20395.250%2,000 2,000 New York
880591EP312/15/20423.500%1,000 1,000 New York
880591DU36/7/20434.962%
(2)
202 
(3)
201 
(3)
New York, Luxembourg
880591EB41/15/20484.875%500 500 New York, Luxembourg
880591EY49/15/20524.250%500 500 New York
880591FC12/1/20555.250%1,250 — New York
880591DZ24/1/20565.375%1,000 1,000 New York
880591EJ79/15/20604.625%1,000 1,000 New York
880591ES79/15/20654.250%1,000 1,000 New York
Subtotal20,628 17,995  
Unamortized discounts, premiums, issue costs, and other (167)(128) 
Total long-term outstanding power bonds, net 20,461 17,867  
Long-term debt of VIEs, net1,632 897 
Total long-term debt, net$22,093 $18,764 
Notes
(1) TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions.  See Put Options above.
(2) The coupon rate represents TVA's effective interest rate.
(3) CUSIP numbers 880591DP4 and 880591DU3 include total net exchange gain from currency transactions of $59 million and $62 million at September 30, 2025 and 2024, respectively
Maturities Due in the Year Ending September 30
Maturities Due in the Year Ending September 30
(in millions)
20262027202820292030ThereafterTotal
Long-term power bonds including current maturities(1)
$1,370 $1,020 $1,272 $220 $2,262 $15,913 $22,057 
Notes
(1) Long-term power bonds do not include non-cash items of foreign currency exchange gain of $59 million, unamortized debt issue costs of $54 million, or net discount on sale of Bonds of $113 million.
Summary of Long-Term Credit Facilities
The following table provides additional information regarding TVA's funding available under the four revolving credit facilities:
Summary of Credit Facilities
At September 30, 2025
(in millions)
Maturity DateFacility LimitLetters of Credit OutstandingCash BorrowingsAvailability
March 2026$150 $38 $— $112 
March 20271,000 135 — 865 
February 2028500 215 — 285 
September 20301,000 110 — 890 
     Total$2,650 $498 $— $2,152 
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions (Tables)
 12 Months Ended
Sep. 30, 2025
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)
For the years ended September 30
(in millions)
Derivatives in Cash Flow Hedging RelationshipObjective of Hedge TransactionAccounting for Derivative
Hedging Instrument		20252024
Currency swapsTo 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$1 $25 
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
For the years ended September 30
(in millions)
Derivatives in Cash Flow Hedging Relationship20252024
Currency swaps$3 $48 
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 $14 million of gains from 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
Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment
Amount of Gain (Loss) Recognized in Income on Derivatives(1)
For the years ended September 30
(in millions)
 
Derivative TypeObjective of DerivativeAccounting for Derivative Instrument20252024
Interest rate swapsTo 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		$45 $(31)
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)
(93)(295)
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 liabilities and assets. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the years ended September 30, 2025 and 2024.
(2) Of the amount recognized in 2025, $77 million and $16 million were reported in Fuel expense and Purchased power expense, respectively. Of the amount recognized in 2024, $245 million and $50 million were reported in Fuel expense and Purchased power expense, respectively.
Fair Values of TVA Derivatives
Fair Values of TVA Derivatives
At September 30
(in millions)
 20252024
Derivatives That Receive Hedge Accounting Treatment:
 BalanceBalance Sheet PresentationBalanceBalance Sheet Presentation
Currency swaps    
£250 million Sterling
$(47)
Accounts payable and accrued liabilities $(4); Other long-term liabilities $(43)
$(49)
Accounts payable and accrued liabilities $(4); Other long-term liabilities $(45)
£150 million Sterling
(68)
Accounts payable and accrued liabilities $(3); Other long-term liabilities $(65)
(67)
Accounts payable and accrued liabilities $(3); Other long-term liabilities $(64)
Derivatives That Do Not Receive Hedge Accounting Treatment:
 BalanceBalance Sheet PresentationBalanceBalance Sheet Presentation
Interest rate swaps    
$1.0 billion notional
$(526)
Accounts payable and accrued liabilities $(13); Accrued interest $(28); Other long-term liabilities $(485)
$(622)
Accounts payable and accrued liabilities $(10), Accrued interest $(26);
Other long-term liabilities
$(586)
$476 million notional
(172)
Accounts payable and accrued liabilities $(5); Accrued interest $(9); Other long-term liabilities $(158)
(218)
Accounts payable and accrued liabilities $(3), Accrued interest $(9);
Other long-term liabilities
$(206)
Commodity contract derivatives 10 
Other current assets $14; Other long-term assets $2; Accounts payable and accrued liabilities $(2); Other long-term liabilities $(4)
2 
Other current assets $5; Other long-term assets $2; Accounts payable and accrued liabilities $(3); Other long-term liabilities $(2)
Commodity derivatives under the FHP(57)
Other long-term assets $8; Accounts payable and accrued liabilities $(57); Other long-term liabilities $(8)
(161)
Accounts payable and accrued liabilities $(99); Other long-term liabilities $(62)
Currency Swaps Outstanding TVA had the following currency swaps outstanding at September 30, 2025:
Currency Swaps Outstanding
Effective Date of Currency Swap ContractAssociated TVA Bond Issues Currency ExposureExpiration Date of SwapOverall Effective
Cost to TVA
2001£250 million20326.587%
2003£150 million20434.962%
Commodity Contract Derivatives
Commodity Contract Derivatives 
At September 30
 20252024
 
Number of Contracts
Notional AmountFair Value (MtM)
(in millions)		Number of ContractsNotional Amount
Fair Value (MtM)
(in millions)
Natural gas contract derivatives53562 million mmBtu$10 45321 million mmBtu$2 
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)
At September 30
(in millions)
20252024
Assets
Commodity contract derivatives 16 7 
Commodity derivatives under the FHP(2)
8 — 
Total derivatives subject to master netting or similar arrangement$24 $7 
Liabilities
Currency swaps$115 $116 
Interest rate swaps(3)
698 840 
Commodity contract derivatives6 5 
Commodity derivatives under the FHP(2)
65 161 
Total derivatives subject to master netting or similar arrangement$884 $1,122 
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 September 30, 2025 or 2024.
(2) At September 30, 2025, the gross derivative asset and gross derivative liability was $28 million and $85 million, respectively, with offsetting amounts for each totaling $20 million. At September 30, 2024, the gross derivative asset and gross derivative liability were $4 million and $165 million, respectively, with offsetting amounts for each totaling $4 million.
(3) Letters of credit of approximately $442 million and $535 million were posted as collateral at September 30, 2025 and 2024, respectively, to partially secure the liability positions of one of the interest rate swaps in accordance with the collateral requirements for this derivative.
Schedule of Derivative Instruments Commodity Contracts under FHP
Commodity Derivatives under Financial Hedging Program(1)
At September 30
20252024
Number of Contracts
Notional Amount
Fair Value (MtM)
(in millions)
Number of Contracts
Notional Amount
Fair Value (MtM)
(in millions)
Natural gas swap contracts295300 million mmBtu$(57)126230 million mmBtu$(161)
Note
(1) Fair value amounts presented are based on the net commodity position with the counterparty. Notional amounts disclosed represent the net value of contractual amounts.
v3.25.3
Fair Value Measurements (Tables) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Fair Value Disclosures [Abstract]    
Transfers Accounted for as Secured Borrowings, Assets, Carrying Amount $ 57 $ 56
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)
For the years ended September 30
(in millions)
FundFinancial Statement Presentation20252024
NDT
Regulatory assets(2)
$221 $324 
ART
Regulatory assets(3)
116 171 
SERPOther income, net3 14 
DCPOther income, net1 2 
Notes
(1) The unrealized gains for the RP were less than $1 million for both the years ended September 30, 2025 and 2024 and therefore were not represented in the table above.
(2) Includes $10 million and $93 million of unrealized gains related to NDT equity securities (excluding commingled funds) for the years ended September 30, 2025 and 2024, respectively.
(3) Includes $7 million and $36 million of unrealized gains related to ART equity securities (excluding commingled funds) for the years ended September 30, 2025 and 2024, respectively. 		 
Fair Value Measurements  
Fair Value Measurements
At September 30, 2025
(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$844 $— $— $844 
Government debt securities(1)(2)
423 50 — 473 
Corporate debt securities(3)
— 411 — 411 
Mortgage and asset-backed securities— 40 — 40 
Institutional mutual funds367 — — 367 
Forward debt securities contracts— 16 — 16 
Cash equivalents and other short-term investments(2)(4)
111 163 — 274 
Private equity funds measured at net asset value(5)
— — — 875 
Private real asset funds measured at net asset value(5)
— — — 467 
Private credit funds measured at net asset value(5)
— — — 278 
Commingled funds measured at net asset value(5)
— — — 1,528 
Total investments1,745 680 — 5,573 
Commodity contract derivatives— 16 — 16 
Commodity derivatives under the FHP— 8 — 8 
Total$1,745 $704 $— $5,597 
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(6)
$— $115 $— $115 
Interest rate swaps— 698 — 698 
Commodity contract derivatives— 6 — 6 
Commodity derivatives under the FHP— 65 — 65 
Total$— $884 $— $884 
Notes
(1) Includes obligations of government-sponsored entities.
(2) There are $423 million of U.S. Treasury securities in Level 1 Government debt securities and $111 million of U.S. Treasury securities in Level 1 Cash equivalents and other short-term investments for a total of $534 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.
(3) Includes both U.S. and foreign debt.
(4) Includes $60 million net payables (interest receivable, dividends receivable, receivables for investments sold, and payables for investments purchased), and $124 million of repurchase agreements in Level 2 Cash equivalents and other short-term investments.
(5) 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.
(6) TVA records currency swaps net of cash collateral received from or paid to the counterparty, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 16 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.
Fair Value Measurements
At September 30, 2024
(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$770 $— $— $770 
Government debt securities(1)(2)
400 57 — 457 
Corporate debt securities(3)
— 378 — 378 
Mortgage and asset-backed securities— 43 — 43 
Institutional mutual funds342 — — 342 
Forward debt securities contracts— 11 — 11 
Cash equivalents and other short-term investments(2)(4)
95 183 — 278 
Private equity funds measured at net asset value(5)
— — — 738 
Private real asset funds measured at net asset value(5)
— — — 432 
    Private credit funds measured at net asset value(5)
— — — 219 
Commingled funds measured at net asset value(5)
— — — 1,300 
Total investments1,607 672 — 4,968 
Commodity contract derivatives— 7 — 7 
Total$1,607 $679 $— $4,975 
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(6)
$— $116 $— $116 
Interest rate swaps— 840 — 840 
Commodity contract derivatives— 5 — 5 
Commodity derivatives under the FHP— 161 — 161 
Total$— $1,122 $— $1,122 
Notes
(1) Includes obligations of government-sponsored entities.
(2) There are $400 million of U.S. Treasury securities in Level 1 Government debt securities and $95 million of U.S. Treasury securities in Level 1 Cash equivalents and other short-term investments for a total of $495 million of U.S. Treasury securities within Level 1 of the fair value hierarchy.
(3) Includes both U.S. and foreign debt.
(4) Includes $78 million net payables (interest receivable, dividends receivable, receivables for investments sold, and payables for investments purchased), and $174 million of repurchase agreements in Level 2 Cash equivalents and other short-term investments.
(5) 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, estimated benchmark yields, 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.
(6) TVA records currency swaps net of cash collateral received from or paid to the counterparty, to the extent such amount is not recorded in Accounts payable and accrued liabilities. See Note 16 — 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 September 30, 2025 and 2024, were as follows:
Estimated Values of Financial Instruments Not Recorded at Fair Value
(in millions)
 At September 30, 2025At September 30, 2024
 Valuation ClassificationCarrying
Amount		Fair
Value		Carrying
Amount		Fair
Value
EnergyRight® receivables, net (including current portion)
Level 2$57 $57 $56 $56 
Loans and other long-term receivables, net (including current portion)Level 286 80 105 99 
EnergyRight® financing obligations (including current portion)
Level 266 74 66 74 
Membership interests of VIEs subject to mandatory redemption (including current portion)Level 216 18 17 19 
Long-term outstanding power bonds, net (including current maturities)Level 221,831 21,967 18,889 19,416 
Long-term debt of VIEs, net (including current maturities)Level 21,681 1,696 934 966 
  
v3.25.3
Other Income (Expense), Net Other Income (Expense), Net (Tables)
 12 Months Ended
Sep. 30, 2025
Other Income and Expenses [Abstract]  
Other Income (Expense), Net
Income and expenses not related to TVA's operating activities are summarized in the following table:
Other Income, Net
For the years ended September 30
(in millions)
 202520242023
Interest income$52 $42 $34 
External services28 17 15 
Gains (losses) on investments14 23 13 
Miscellaneous(2)(11)(1)
Total other income, net$92 $71 $61 
v3.25.3
Benefit Plans Benefit Plans (Tables)
 12 Months Ended
Sep. 30, 2025
Retirement Benefits [Abstract]  
Obligations and Funded Status
The changes in plan obligations, assets, and funded status for the years ended September 30, 2025 and 2024, were as follows:
Obligations and Funded Status
For the years ended September 30
(in millions)
859,400,000 Pension BenefitsOther Post-Retirement Benefits
867,300,000 2025202420252024
Change in benefit obligation    
Benefit obligation at beginning of year$11,002 $10,099 $353 $347 
Service cost32 29 11 11 
Interest cost526 579 17 21 
Plan participants' contributions3 3 — — 
Collections(1)
— — 12 12 
Actuarial (gain) loss (457)1,059 1.1(67)(4)
Curtailments (2)
(1)— — — 
Special/contractual termination benefits (3)
— — 1 — 
Net transfers (to) from variable fund/401(k) plan2 5 — — 
Expenses paid(7)(6)— — 
Benefits paid(799)(766)(36)(34)
Benefit obligation at end of year10,301 11,002 291 353 
Change in plan assets    
Fair value of net plan assets at beginning of year8,673 8,129 — — 
Actual return on plan assets412 1,004 — — 
Plan participants' contributions3 3 — — 
Collections(1)
— — 12 12 
Net transfers (to) from variable fund/401(k) plan2 5 — — 
Employer contributions310 304 24 22 
Expenses paid(7)(6)— — 
Benefits paid(799)(766)(36)(34)
Fair value of net plan assets at end of year8,594 8,673 — — 
Funded status$(1,707)$(2,329)$(291)$(353)
Note
(1) Collections include retiree contributions as well as provider discounts and rebates.
(2) The 2025 pension obligation plan curtailment gain is a result of the amendments to the TVA SERP in which participants ceased accruing new benefits effective September 30, 2025. This reduced the projected benefit obligation by $1 million.
(3) Special/contractual termination benefits for certain eligible employees related to TVA's restructuring activities. For 2025, the other post-retirement plan recognized a loss that increased the obligation by $1 million as a result of special/contractual termination benefits for certain eligible employees related to TVA’s restructuring activities. See Note 3 — Restructuring.
Amounts Recognized on TVA's Consolidated Balance Sheets
Amounts related to these benefit plans recognized on TVA's Consolidated Balance Sheets consist of regulatory assets and liabilities that have not been recognized as components of net periodic benefit cost at September 30, 2025 and 2024, and the funded status of TVA's benefit plans, which are included in Accounts payable and accrued liabilities and Post-retirement and post-employment benefit obligations:
Amounts Recognized on TVA's Consolidated Balance Sheets
At September 30
(in millions)
 Pension BenefitsOther Post-Retirement Benefits
 2025202420252024
Regulatory assets (liabilities)$1,531 $1,979 $(131)$(81)
Accounts payable and accrued liabilities(9)(6)(17)(20)
Pension and post-retirement benefit obligations(1)
(1,698)(2,323)(274)(333)
Note
(1) The table above excludes $208 million of post-employment benefit costs and $3 million of RP costs at September 30, 2025, and $230 million of post-employment benefit costs and $1 million of RP costs at September 30, 2024 that are recorded in Post-retirement and post-employment benefit obligations on the Consolidated Balance Sheets.
Post-Retirement Benefit Costs Deferred as Regulatory Assets
Unrecognized amounts included in regulatory assets or liabilities yet to be recognized as components of accrued benefit cost at September 30, 2025 and 2024, consisted of the following:
Post-Retirement Benefit Costs Deferred as Regulatory Assets (Liabilities)
At September 30
(in millions)
 Pension BenefitsOther Post-Retirement Benefits
 2025202420252024
Unrecognized prior service credit$(158)$(247)$(25)$(42)
Unrecognized net loss (gain)1,689 2,226 (106)(39)
Total regulatory assets (liabilities)$1,531 $1,979 $(131)$(81)
Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets
Information for the pension projected benefit obligation ("PBO") in excess of plan assets and other post-retirement accumulated postretirement benefit obligation ("APBO") has been disclosed in the Obligations and Funded Status table above. The following table provides the pension plan accumulated benefit obligation ("ABO") in excess of plan assets. The other post-retirement plans are unfunded or have no plan assets.
Accumulated Benefit Obligations in Excess of Plan Assets
At September 30
(in millions)
 20252024
Accumulated benefit obligation$10,278 $10,971 
Fair value of net plan assets8,594 8,673 
Components of Net Periodic Benefit Cost
The components of net periodic benefit cost for the years ended September 30, 2025, 2024, and 2023 were as follows:
Components of Net Periodic Benefit Cost (1)
For the years ended September 30
(in millions)
 Pension BenefitsOther Post-Retirement Benefits
 202520242023202520242023
Service cost$32 $29 $32 $11 $11 $10 
Interest cost526 579 568 17 21 18 
Expected return on plan assets(505)(494)(492)— — — 
Amortization of prior service credit(89)(89)(88)(17)(17)(17)
Recognized net actuarial loss (gain)173 99 135 (1)(1)(2)
Total net periodic benefit cost137 124 155 10 14 9 
Special/contractual termination benefits(2)
— — — 1 — — 
Amount expensed due to actions of regulator— — 77 — — — 
Total net periodic benefit cost$137 $124 $232 $11 $14 $9 
Note
(1) The components of total benefit cost other than the service cost component are included in Other net periodic benefit cost on the Consolidated Statements of Operations.
(2) Special/contractual termination benefits for certain eligible employees related to TVA's restructuring activities. See Note 3 — Restructuring.
Sensitivity to Certain Changes in Pension Assumptions The following chart reflects the sensitivity of pension cost to changes in certain actuarial assumptions:
Sensitivity to Certain Changes in Pension Assumptions
 
 
Actuarial Assumption
Change in Assumption
Impact on 2025 Pension Cost
(in millions)
Impact on 2025 Projected Benefit Obligation
(in millions)
Discount rate(0.25)%$12 $241 
Rate of return on plan assets(0.25)%19 N/A
Cost of living adjustments0.25 %20 168 
Asset Holdings and Fair Value Measurements At September 30, 2025 and 2024, the asset holdings of TVARS included the following (prior year amounts have been reclassified to conform to the current presentation):
Asset Holdings of TVARS
  Plan Assets at September 30
Asset CategoryTarget Allocation20252024
Fixed Income68 %59 %58 %
Equity20 %23 %25 %
Real Assets12 %18 %17 %
Total100 %100 %100 %
Fair Value Measurements

    The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2025:
TVA Retirement System
At September 30, 2025
(in millions)
 
Total(1)(2)
Quoted Prices in Active Markets for Identical
Assets/Liabilities
(Level 1)		Significant Other
Observable Inputs
(Level 2)		Significant
Unobservable
Inputs
(Level 3)
Assets    
Equity securities$740 $727 $— $13 
Preferred securities2 — — 2 
Debt securities   
Corporate debt securities770 — 764 6 
Mortgage and asset-backed securities523 — 520 3 
    Debt securities issued by U.S. Treasury433 433 — — 
Debt securities issued by foreign governments
18 — 18 — 
Debt securities issued by state/local governments
17 — 17 — 
Commingled funds measured at net asset value(3)
Equity286 — — — 
Debt1,845 — — — 
Institutional mutual funds196 196 — — 
Cash equivalents and other short-term investments181 10 171 — 
Private credit funds measured at net asset value(3)
1,175 — — — 
Private equity funds measured at net asset value(3)
1,290 — — — 
Private real asset funds measured at net asset value(3)
1,209 — — — 
Securities lending collateral142 — 142 — 
Derivatives    
Futures
3 3 — — 
Swaps7 — 7 — 
Total assets$8,837 $1,369 $1,639 $24 
Notes
(1)  Excludes approximately $101 million in net payables associated with security purchases and sales and various other payables.
(2)  Excludes a $142 million payable for collateral on loaned securities in connection with TVARS's participation in securities lending programs.
(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, estimated benchmark yields, 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 as the fair value of net plan assets.
    The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2024:
TVA Retirement System
At September 30, 2024
(in millions)
 
Total(1)(2)
Quoted Prices in Active Markets for Identical
Assets/Liabilities
(Level 1)		Significant Other
Observable Inputs
(Level 2)		Significant
Unobservable
Inputs
(Level 3)
Assets    
Equity securities$670 $668 $— $2 
Preferred securities3 — 2 1 
Debt securities   
Corporate debt securities1,122 — 1,121 1 
Mortgage and asset-backed securities572 — 511 61 
Debt securities issued by U.S. Treasury543 543 — — 
Debt securities issued by foreign governments19 — 19 — 
Debt securities issued by state/local governments23 — 23 — 
Commingled funds measured at net asset value(3)
Equity245 — — — 
Debt1,236 — — — 
Institutional mutual funds180 180 — — 
Cash equivalents and other short-term investments249 5 244 — 
Private credit funds measured at net asset value(3)
1,126 — — — 
Private equity funds measured at net asset value(3)
1,580 — — — 
Private real asset funds measured at net asset value(3)
1,150 — — — 
Securities lending collateral235 — 235 — 
Derivatives
Swaps
6 — 6 — 
Total assets$8,959 $1,396 $2,161 $65 
Liabilities    
Derivatives
Futures$1 $1 $— $— 
Swaps3 — 3 — 
Total liabilities$4 $1 $3 $— 
Notes
(1)  Excludes approximately $47 million in net payables associated with security purchases and sales and various other payables.
(2)  Excludes a $235 million payable for collateral on loaned securities in connection with TVARS's participation in securities lending programs.
(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, estimated benchmark yields, 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 as the fair value of net plan assets.
Fair Value Measurements Using Significant Unobservable Inputs
The following table provides a reconciliation of beginning and ending balances of pension plan assets measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3):
Fair Value Measurements Using Significant Unobservable Inputs
(in millions)
 Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Balance at September 30, 2023
$60 
Net realized/unrealized gains (losses)2 
Purchases, sales, issuances, and settlements (net)10 
Transfers in and/or out of Level 3(7)
Balance at September 30, 2024
65 
Net realized/unrealized gains (losses)10 
Purchases, sales, issuances, and settlements (net)(18)
Transfers in and/or out of Level 3(33)
Balance at September 30, 2025
$24 
Estimated Future Benefit Payments
Cash Flows

Estimated Future Benefit Payments.  The following table sets forth the estimated future benefit payments under the benefit plans.
Estimated Future Benefits Payments
At September 30, 2025
(in millions)
 
Pension
Benefits(1)
Other Post-Retirement Benefits
2026$827 $17 
2027826 17 
2028826 16 
2029819 16 
2030808 16 
2031 - 20353,885 93 
Note
(1) Participants are assumed to receive the Fixed Fund in a lump sum in lieu of available annuity options allowed for certain grandfathered participants resulting in higher estimated pension benefits payments.
Amounts recognized on Consolidated Balance Sheets
Amounts Recognized on TVA's Consolidated Balance Sheets
At September 30
(in millions)
 20252024
Accounts payable and accrued liabilities$25 $28 
Post-retirement and post-employment benefit obligations208 230 
v3.25.3
Commitments and Contingencies (Tables)
 12 Months Ended
Sep. 30, 2025
Commitments and Contingencies Disclosure [Abstract]  
Unfunded loan commitments At September 30, 2025, TVA had no commitments under unfunded loan commitments for 2026 through 2030.
v3.25.3
Related Parties Related Parties (Tables)
 12 Months Ended
Sep. 30, 2025
Related Party Transactions [Abstract]  
Related Party Transactions Transactions with agencies of the federal government were as follows:
Related Party Transactions
At or for the years ended September 30
(in millions)
 202520242023
Revenue from sales of electricity$132 $118 $120 
Other income309 273 282 
Expenditures
Operating expenses264 241 234 
Additions to property, plant, and equipment13 12 8 
Cash and cash equivalents31 31 31 
Accounts receivable, net89 81 87 
Investment funds534 495 391 
Long-term accounts receivable43 35 38 
Accounts payable and accrued liabilities41 45 42 
Long-term power bonds, net4 3 1 
Return on power program appropriation investment8 7 6 
v3.25.3
Revenue (Tables)
 12 Months Ended
Sep. 30, 2025
Revenue from Contract with Customer [Abstract]  
Revenues
Revenues

TVA recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount to which the entity expects to be entitled in exchange for those goods or services. For the generation and transmission of electricity, this is generally at the time the power is delivered to a metered customer delivery point for the customer's consumption or distribution. As a result, revenues from power sales are recorded as electricity is delivered to customers. In addition to power sales invoiced and recorded during the month, TVA accrues estimated unbilled revenues for power sales provided to five customers whose billing date occurs prior to the end of the month.  Exchange power sales are presented in the accompanying Consolidated Statements of Operations as a component of sales of electricity. Exchange power sales are sales of excess power after meeting TVA native load and directly served requirements.  Native load refers to the customers on whose behalf a company, by statute, franchise, regulatory requirement, or contract, has undertaken an obligation to serve. TVA
engages in other arrangements in addition to power sales. Certain other revenue from activities related to TVA's overall mission is recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income, net.
Disaggregation of Revenue [Table Text Block] TVA's operating revenues by state for each of the last three years are detailed in the table below:
Operating Revenues By State
For the years ended September 30
(in millions)
 202520242023
Alabama
$1,995 $1,768 $1,731 
Georgia
329 295 284 
Kentucky
850 776 773 
Mississippi
1,254 1,150 1,146 
North Carolina
88 89 89 
Tennessee
8,915 7,998 7,819 
Virginia
52 47 46 
Subtotal13,483 12,123 11,888 
Off-system sales7 8 14 
Revenue capitalized during pre-commercial plant operations(1)
(4)(3)(3)
Revenue from sales of electricity13,486 12,128 11,899 
Other revenue186 186 155 
Total operating revenues$13,672 $12,314 $12,054 
Note
(1) Represents revenue capitalized during pre-commercial operations at Johnsonville Aeroderivative CT Units 21-30 in 2025 and Paradise CT Units 5-7 in 2024.
Revenue from External Customers by Products and Services TVA's operating revenues by customer type for each of the last three years are detailed in the table below:
Operating Revenues by Customer Type
For the years ended September 30
(in millions)
 202520242023
Revenue from sales of electricity  
Local power companies$12,334 $11,138 $10,903 
Industries directly served1,017 868 864 
Federal agencies and other139 125 135 
Revenue capitalized during pre-commercial plant operations(1)
(4)(3)(3)
Revenue from sales of electricity13,486 12,128 11,899 
Other revenue186 186 155 
Total operating revenues$13,672 $12,314 $12,054 
Note
(1) Represents revenue capitalized during pre-commercial operations at Johnsonville Aeroderivative CT Units 21-30 in 2025 and Paradise CT Units 5-7 in 2024.
Schedule of Long-Term Contracts for Purchase of Electric Power
The number of LPCs by contract arrangement, the revenues derived from such arrangements for 2025, and the percentage those revenues comprised of TVA's total operating revenues for 2025, are summarized in the table below:
TVA Local Power Company Contracts
At or for the year ended September 30, 2025
Contract Arrangements(1)
Number of LPCs Revenue from Sales of Electricity to LPCs
(in millions)		Percentage of Total Operating Revenues
20-year termination notice148 $10,636 77.8 %
5-year termination notice5 1,698 12.4 %
Total153 $12,334 90.2 %
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.
v3.25.3
Leases (Table Text Block)
 12 Months Ended
Sep. 30, 2025
Leases [Abstract]  
Amounts Recognized on Balance Sheets The following table provides information regarding the presentation of leases on the Consolidated Balance Sheets:
Amounts Recognized on TVA's Consolidated Balance Sheets
At September 30
(in millions)
20252024
Assets
  OperatingOperating lease assets, net of amortization$113 $149 
  FinanceFinance leases663 729 
Total lease assets$776 $878 
Liabilities
Current
  OperatingAccounts payable and accrued liabilities$46 $63 
  FinanceAccounts payable and accrued liabilities86 80 
Non-current
  OperatingOther long-term liabilities63 88 
  FinanceFinance lease liabilities640 700 
Total lease liabilities$835 $931 
Amounts Recognized on Statements of Cash Flows
The following table contains additional information with respect to cash and non-cash activities related to leases:
Amounts Recognized on TVA's Consolidated Statements of Cash Flows
For the years ended September 30
(in millions)
202520242023
Operating cash flows for operating leases$72 $78 $77 
Operating cash flows for finance leases46 37 43 
Financing cash flows for finance leases82 76 56 
Lease assets obtained in exchange for lease obligations (non-cash)
Operating leases$14 $115 $84 
Finance leases28 230 3 
Weighted Averages
TVA has certain finance leases under PPAs under which the present value of the minimum lease payments exceeds the fair value of the related lease asset at the date of measurement.  This resulted in an interest rate that was higher than TVA's incremental borrowing rate. The weighted average remaining lease terms in years and the weighted average discount rate for TVA's operating and finance leases were as follows:
Weighted Averages
At September 30
20252024
Weighted average remaining lease terms
Operating leases3 years4 years
   Finance leases(1)
8 years9 years
Weighted average discount rate(2)
Operating leases4.2%4.3%
Finance leases17.0%17.6%
Note
(1) One of TVA's finance leases includes an option period to extend, which TVA is reasonably certain to exercise.
(2) The discount rate is calculated using the rate implicit in a lease if it is readily determinable. If the rate used by the lessor is not readily determinable, TVA uses its incremental borrowing rate as permitted by accounting guidance. The incremental borrowing rate is influenced by TVA's credit rating and lease term and as such may differ for individual leases, embedded leases, or portfolios of leased assets.
Future Minimum Lease Payments The following table presents maturities of lease liabilities and a reconciliation of the undiscounted cash flows to lease liabilities at September 30, 2025:
Future Minimum Lease Payments
Minimum payments outstanding at September 30, 2025
(in millions)
Operating leases
2026$50 
202735 
202819 
20294 
20302 
Thereafter6 
Minimum annual payments116 
Less: present value discount(7)
Operating present value of net minimum lease payments$109 
Finance leases
2026$144 
2027142 
2028137 
2029134 
2030133 
   Thereafter340 
Minimum annual payments1,030 
Less: amount representing interest(304)
Finance present value of net minimum lease payments$726 
Lease, Cost TVA's leases consist primarily of railcars, equipment, real estate/land, power generating facilities, and gas pipelines. TVA's leases have various terms and expiration dates remaining from less than one year to 21 years. The components of lease costs were as follows:
Lease Costs
For the years ended September 30
(in millions)
202520242023
Operating lease costs(1)
$73 $77 $69 
Variable lease costs(1)(5)
337 258 134 
Short-term lease costs(1)
15 10 18 
Finance lease costs
Amortization of lease assets(2)
91 79 57 
Interest on lease liabilities(3)(4)
46 37 43 
Total finance lease costs137 116 100 
     Total lease costs$562 $461 $321 

Notes
(1) Costs are included in Operating and maintenance expense, Fuel expense, Purchased power expense, and Tax equivalents expense on the Consolidated Statements of Operations.
(2) Expense is included in Depreciation and amortization expense on the Consolidated Statements of Operations.
(3) Expense is included in Interest expense on the Consolidated Statements of Operations.
(4) Certain finance leases receive regulatory accounting treatment and are reclassified to Fuel expense and Purchased power expense.
(5) Variable lease costs include costs related to variable payments that are based on energy production levels, which are allocated to expense based on the determination of lease and non-lease components associated with the underlying agreements.
v3.25.3
Restructuring and Related Activities (Tables)
 12 Months Ended
Sep. 30, 2025
Restructuring and Related Activities [Abstract]  
Restructuring and Related Costs The table below summarizes the activity related to severance costs:
Severance Cost Liability Activity
(in millions)
Severance cost liability at September 30, 2024$— 
Liabilities incurred during the period40 
Actual costs paid during the period(29)
Severance cost liability at September 30, 2025
$11 
v3.25.3
Segment Reporting (Tables) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Segment Reporting [Abstract]      
Schedule of Segment Reporting Information, by Segment As the segment measure used by the CODM is net income, no reconciliation is necessary.
For the years ended September 30
(in millions)
2025
2024(2)
2023(2)
Base Revenue$9,415 $8,725 $7,863 
Fuel Revenue4,068 3,398 4,025 
Other Revenue189191 166 
Total Operating Revenue13,672 12,314 12,054 
Fuel2,376 2,169 2,549 
Purchased Power2,106 1,581 1,633 
Operating and Maintenance3,717 3,641 3,372 
Depreciation and Amortization2,271 2,138 2,213 
Interest Expense1,196 1,066 1,056 
Tax Equivalents633 557 593 
Other Segment Items(1)
13 27 138 
Net Income$1,360 $1,135 $500 
Notes
(1) Other segment items include non-utility related miscellaneous income and expenses, pension and post-retirement benefit costs, and interest income.
(2) Prior period amounts have been reclassified to conform to the current period presentation resulting from the retrospective adoption of ASU 2023-07, Segment Reporting. Expanded segment disclosures were not required in the comparative periods presented because the company operated, and continues to operate, as a single reportable segment for which detailed segment expense disclosures were not previously required.
    
Regulated Operating Revenue $ 13,486 $ 12,128 $ 11,899
Segment Reporting, Other Segment Item, Amount 13 27 138
Corporate Segment      
Regulated Operating Revenue 9,415 8,725 7,863
Corporate Segment and Other Operating Segment      
Regulated Operating Revenue $ 4,068 $ 3,398 $ 4,025
v3.25.3
Summary of Significant Accounting Policies - General (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Sep. 30, 2022
USD ($)
Sep. 30, 2015
USD ($)
Accounting Policies [Abstract]          
Cash and Cash Equivalent $ 1,576 $ 502      
Reimbursements from DOE 334        
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents 1,597 523 $ 521 $ 520  
Accounts receivable from DOE 6        
Appropriation-investment power program $ 258 258     $ 1,000
Population of Service Area [Line Items]          
Population of service area | Units 10,000,000        
Cash and Cash Equivalent $ 1,576 502      
Restricted Cash and Cash Equivalent, Noncurrent 21 21      
Accumulated depreciation $ 38,716 $ 38,793      
v3.25.3
Summary of Significant Accounting Policies - Reclassificatons (Details)
$ in Millions
Sep. 30, 2025
USD ($)
Reclassifications  
Finance Lease, Liability $ 726
v3.25.3
Summary of Significant Accounting Policies - Allowance for Uncollectible Accounts (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Financing Receivable, after Allowance for Credit Loss $ 80 $ 99
Allowance for uncollectible accounts - receivables 14 1 [1]
Accounts and Financing Receivable, Allowance for Credit Loss 2 2
Holly Springs    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Allowance for uncollectible accounts - receivables 14  
Reported Value Measurement    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Financing Receivable, after Allowance for Credit Loss $ 86 $ 105
[1] 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, among other considerations. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts. At September 30, 2025, the allowance for uncollectible accounts included $14 million related to one LPC customer.
(2) The allowance for uncollectible accounts was less than $1 million at September 30, 2024.
In addition, the Inflation Reduction Act of 2022 ("IRA") makes credits available to certain tax-exempt entities, including TVA. Obtaining this funding requires TVA to meet certain requirements, to submit informational returns to the Internal Revenue Service ("IRS"), and to retain adequate books and records to support its filings. TVA records the credit when there is reasonable assurance that the credit will be received, and TVA complies with all conditions attached to the eligibility of the credit. The credit is recognized as a reduction of the asset and/or expense based on what the credits are intended to reimburse. At September 30, 2025, TVA recorded $72 million in Accounts receivable, net, which is classified as Other receivables above, related to these tax credits; $51 million was recorded as a reduction of Net completed plant; $19 million was recorded to reduce Operating and maintenance expense; and $2 million related to interest was recorded to Other income, net. There were no tax credits recorded in 2024. TVA received $26 million in October 2025 related to these credits.
v3.25.3
Summary of Significant Accounting Policies - Property, Plant, and Equipment, and Depreciation (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Property, Plant, and Equipment, and Depreciation      
Depreciation $ 1,900 $ 1,800 $ 1,900
Composite depreciation rate for completed plant 3.04% 2.92% 3.14%
Reacquired Rights $ 301 $ 312  
Amortization of Reacquired Rights $ 11 11 $ 10
Capitalized software amortization period 7 years    
Accumulated Amortization of Reacquired Rights $ 74 $ 63  
Amortization Reacquired Rights, Year 1 11    
Amortization Reacquired Rights, Year 2 12    
Amortization Reacquired Rights, Year 3 11    
Amortization Reacquired Rights, Year 4 11    
Amortization Reacquired Rights, Year 5 12    
Amortization Reacquired Rights, Year Thereafter 244    
Reimbursements from DOE 334    
Accounts receivable from DOE $ 6    
Nuclear      
Property, Plant, and Equipment, and Depreciation      
Composite depreciation rate for completed plant 2.71% 2.71% 2.73%
Coal-fired      
Property, Plant, and Equipment, and Depreciation      
Composite depreciation rate for completed plant 4.82% 4.13% 4.98%
Hydroelectric      
Property, Plant, and Equipment, and Depreciation      
Composite depreciation rate for completed plant 1.82% 1.83% 1.82%
Gas and oil-fired      
Property, Plant, and Equipment, and Depreciation      
Composite depreciation rate for completed plant 3.16% 3.31% 3.17%
Transmission      
Property, Plant, and Equipment, and Depreciation      
Composite depreciation rate for completed plant 1.55% 1.52% 1.52%
Other      
Property, Plant, and Equipment, and Depreciation      
Composite depreciation rate for completed plant 5.22% 4.98% 4.43%
v3.25.3
Summary of Significant Accounting Policies - Energy Prepayment Obligations and Discounts on Sales (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Energy Prepayment Obligations and Discounts on Sales    
Accounts Receivable, Allowance for Credit Loss, Current $ 14 $ 1 [1]
[1] 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, among other considerations. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts. At September 30, 2025, the allowance for uncollectible accounts included $14 million related to one LPC customer.
(2) The allowance for uncollectible accounts was less than $1 million at September 30, 2024.
In addition, the Inflation Reduction Act of 2022 ("IRA") makes credits available to certain tax-exempt entities, including TVA. Obtaining this funding requires TVA to meet certain requirements, to submit informational returns to the Internal Revenue Service ("IRS"), and to retain adequate books and records to support its filings. TVA records the credit when there is reasonable assurance that the credit will be received, and TVA complies with all conditions attached to the eligibility of the credit. The credit is recognized as a reduction of the asset and/or expense based on what the credits are intended to reimburse. At September 30, 2025, TVA recorded $72 million in Accounts receivable, net, which is classified as Other receivables above, related to these tax credits; $51 million was recorded as a reduction of Net completed plant; $19 million was recorded to reduce Operating and maintenance expense; and $2 million related to interest was recorded to Other income, net. There were no tax credits recorded in 2024. TVA received $26 million in October 2025 related to these credits.
v3.25.3
Summary of Significant Accounting Policies - Leases (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Leases      
Finance lease under PPA $ 509 $ 550  
Operating lease under PPA 75 121  
Operating cash flows for operating leases 72 $ 78 $ 77
Finance Lease, Liability, Payment, Due $ 1,030    
v3.25.3
Summary of Significant Accounting Policies - Pre-commercial Plant Ops (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Revenues from External Customers and Long-Lived Assets [Line Items]      
Revenue capitalized during pre-commercial operations $ 4 $ 3 $ 3
Pre-commercial Operations - Capitalized Revenue      
Revenues from External Customers and Long-Lived Assets [Line Items]      
Unregulated Operating Revenue (4) 3 $ 3
Paradise CT Units 5-7      
Revenues from External Customers and Long-Lived Assets [Line Items]      
Fuel capitalized during pre-commercial ops   3  
Paradise CT Units 5-7 | Pre-commercial Operations - Capitalized Revenue      
Revenues from External Customers and Long-Lived Assets [Line Items]      
Unregulated Operating Revenue   $ 3  
Johnsonville Aeroderivative CT Units 21-30      
Revenues from External Customers and Long-Lived Assets [Line Items]      
Fuel capitalized during pre-commercial ops 7    
Johnsonville Aeroderivative CT Units 21-30 | Pre-commercial Operations - Capitalized Revenue      
Revenues from External Customers and Long-Lived Assets [Line Items]      
Unregulated Operating Revenue $ 4    
v3.25.3
Impact of New Accounting Standards and Interpretations (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Lessee, Lease, Description [Line Items]    
Operating Lease, Right-of-Use Asset $ 113 $ 149
v3.25.3
Accounts Receivable, Net Accounts Receivable, Net (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Power receivables $ 1,908 $ 1,683
Other receivables 225 118
Accounts receivable, net 2,119 1,801
Allowance for uncollectible accounts - receivables 14 1 [1]
Accounts Receivable, Allowance for Credit Loss (14) $ 0
Tax Credits Reduce Net Completed Plant 51  
Tax Credits Reduce Operating & Maintenance Expense 19  
Tax Credits Interest Income Recorded 2  
Other Receivables, Net, Current 72  
Investment Tax Credit 26  
Holly Springs    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Allowance for uncollectible accounts - receivables $ 14  
[1] 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, among other considerations. See Note 1 — Summary of Significant Accounting Policies — Allowance for Uncollectible Accounts. At September 30, 2025, the allowance for uncollectible accounts included $14 million related to one LPC customer.
(2) The allowance for uncollectible accounts was less than $1 million at September 30, 2024.
In addition, the Inflation Reduction Act of 2022 ("IRA") makes credits available to certain tax-exempt entities, including TVA. Obtaining this funding requires TVA to meet certain requirements, to submit informational returns to the Internal Revenue Service ("IRS"), and to retain adequate books and records to support its filings. TVA records the credit when there is reasonable assurance that the credit will be received, and TVA complies with all conditions attached to the eligibility of the credit. The credit is recognized as a reduction of the asset and/or expense based on what the credits are intended to reimburse. At September 30, 2025, TVA recorded $72 million in Accounts receivable, net, which is classified as Other receivables above, related to these tax credits; $51 million was recorded as a reduction of Net completed plant; $19 million was recorded to reduce Operating and maintenance expense; and $2 million related to interest was recorded to Other income, net. There were no tax credits recorded in 2024. TVA received $26 million in October 2025 related to these credits.
v3.25.3
Inventories, Net Inventories, Net (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Inventories, Net    
Materials and supplies inventory $ 986 $ 931
Fuel inventory 278 286
Renewable energy certificates/emissions allowance inventory, net 12 11
Allowance for inventory obsolescence (83) (73)
Inventories, net $ 1,193 $ 1,155
v3.25.3
Deferred Costs, Capitalized, Prepaid, and Other Assets (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]    
Inventory, Work in Process, Gross $ 69 $ 41
Fair value 12 64
Other current assets 162 120
Prepaid Insurance 16 19
Other Assets, Miscellaneous, Current 12 7
Prepaid software maintenance 25 22
Other Intangible Assets, Net 114 35
Prepaid Expense and Other Assets, Current 16 7
Prepaid Expense, Current $ 7 $ 6
v3.25.3
Net Completed Plant Net Completed Plant (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Completed Plant    
Accumulated depreciation $ 38,716 $ 38,793
Net completed plant 32,858 32,196
Property, Plant and Equipment, Gross 71,574 70,989
Coal-fired    
Completed Plant    
Completed plant cost 19,029 20,177
Accumulated depreciation 15,760 16,635
Net completed plant 3,269 3,542
Gas and oil-fired    
Completed Plant    
Completed plant cost 7,746 7,051
Accumulated depreciation 2,274 2,112
Net completed plant 5,472 4,939
Nuclear    
Completed Plant    
Completed plant cost 27,091 26,800
Accumulated depreciation 14,682 14,149
Net completed plant 12,409 12,651
Transmission    
Completed Plant    
Completed plant cost 10,323 9,964
Accumulated depreciation 3,542 3,450
Net completed plant 6,781 6,514
Hydroelectric    
Completed Plant    
Completed plant cost 4,391 4,307
Accumulated depreciation 1,352 1,288
Net completed plant 3,039 3,019
Other electrical plant    
Completed Plant    
Completed plant cost 2,068 1,763
Accumulated depreciation 678 737
Net completed plant 1,390 1,026
Multipurpose dams    
Completed Plant    
Completed plant cost 900 900
Accumulated depreciation 419 413
Net completed plant 481 487
Other stewardship    
Completed Plant    
Completed plant cost 26 27
Accumulated depreciation 9 9
Net completed plant $ 17 $ 18
v3.25.3
Other Long-Term Assets (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Assets, Noncurrent [Abstract]      
Financing Receivable, after Allowance for Credit Loss, Noncurrent $ 83 $ 84  
Financing Receivable, after Allowance for Credit Loss, Current 3 21  
Prepaid capital assets 81 29  
Total other long-term assets 506 344  
Other Long-Term Assets      
Other Assets, Miscellaneous, Current 12 7  
Other Intangible Assets, Net 114 35  
Prepaid Expense, Current 7 6  
Prepaid long-term service agreements, current 16 7  
Transfers Accounted for as Secured Borrowings, Assets, Carrying Amount 57 56  
Prepaid Expense and Other Assets, Noncurrent 89 62  
Prepaid capital assets 81 29  
Accounts and Financing Receivable, Allowance for Credit Loss 2 2  
Hosting Arrangement, Service Contract, Implementation Cost, Expense, Amortization 14 15 $ 7
Accounts Receivable [Member]      
Other Long-Term Assets      
Transfers Accounted for as Secured Borrowings, Assets, Carrying Amount 12 12  
Other Noncurrent Assets [Member]      
Assets, Noncurrent [Abstract]      
Other Assets, Miscellaneous, Noncurrent 84 88  
Other Long-Term Assets      
Other Assets, Miscellaneous, Noncurrent 84 88  
Transfers Accounted for as Secured Borrowings, Assets, Carrying Amount 45 44  
Other current assets      
Other Long-Term Assets      
Other Intangible Assets, Net 3 13  
EnergyRight loan reserve      
Other Long-Term Assets      
Accounts and Financing Receivable, Allowance for Credit Loss 1 1  
Economic development loan specific loan reserve      
Other Long-Term Assets      
Accounts and Financing Receivable, Allowance for Credit Loss 1 1  
Other Noncurrent Assets [Member]      
Assets, Noncurrent [Abstract]      
Commodity contract derivative assets 10 2  
Other Long-Term Assets      
Commodity contract derivative assets $ 10 $ 2  
Energy Right      
Other Long-Term Assets      
Number of days in default 180 days    
Minimum | Energy Right      
Other Long-Term Assets      
EnergyRight loan terms 5 years    
Maximum | Energy Right      
Other Long-Term Assets      
EnergyRight loan terms 10 years    
v3.25.3
Regulatory Assets and Liabilities Regulatory Assets and Liabilities (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Regulatory Assets and Liabilities      
Non-current regulatory liabilities $ 141 $ 83  
Current regulatory assets 127 191  
Regulatory assets 8,047 9,408  
Net unrealized gains (losses) (12) (64)  
Regulatory Assets 8,174 9,599  
Current regulatory liabilities 228 174  
Regulatory asset amount expensed 63 71 $ 31
Regulatory Liabilities 369 257  
Environmental Costs Recognized, Capitalized 308 215  
Regulatory Asset      
Regulatory Assets and Liabilities      
Regulatory assets 168 154  
Unrealized losses on interest rate derivatives      
Regulatory Assets and Liabilities      
Current regulatory assets 57 54  
Regulatory assets 316 447  
Non-nuclear decommissioning costs      
Regulatory Assets and Liabilities      
Regulatory assets 5,563 6,187  
Pension Costs [Member]      
Regulatory Assets and Liabilities      
Regulatory assets 1,531 1,979  
Unrealized gains/losses on commodity derivatives      
Regulatory Assets and Liabilities      
Current regulatory assets 59 102  
Regulatory assets 12 64  
Deferred Fuel Costs [Member]      
Regulatory Assets and Liabilities      
Current regulatory assets 0 35  
Nuclear decommissioning costs      
Regulatory Assets and Liabilities      
Regulatory assets 149 362  
Other current assets      
Regulatory Assets and Liabilities      
Current regulatory assets 11 0  
Unrealized gains/losses on commodity derivatives      
Regulatory Assets and Liabilities      
Non-current regulatory liabilities 10 2  
Current regulatory liabilities 14 5  
Deferred other post-retirement benefits cost      
Regulatory Assets and Liabilities      
Non-current regulatory liabilities 131 81  
Fuel cost adjustment tax equivalents      
Regulatory Assets and Liabilities      
Current regulatory liabilities 203 169  
Deferred Fuel Costs [Member]      
Regulatory Assets and Liabilities      
Current regulatory liabilities $ 11 $ 0  
v3.25.3
Variable Interest Entities (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Oct. 02, 2024
Sep. 30, 2013
Sep. 30, 2012
Liabilities            
Current maturities of long-term debt of variable interest entities issued at par $ 49 $ 37        
Liabilities, Current 5,607 5,873        
Other long-term liabilities 1,606 1,712        
Long-term debt of variable interest entities, net 1,632 897        
VIE Financing            
Face Amount $ 40       $ 360  
Rate of Return SHLLC 7.00%          
Accrued interest $ 29 9        
Minimum payments on membership interests subject to mandatory redemption, due in next twelve months 1          
Minimum payments on membership interests subject to mandatory redemption, due in year two 1          
Minimum payments on membership interests subject to mandatory redemption, due in year three 1          
Minimum payments on membership interests subject to mandatory redemption, due in year four 2          
Minimum payments on membership interests subject to mandatory redemption, due in year five 2          
Minimum payments on membership interests subject to mandatory redemption, due thereafter 9          
2018 1,370          
2019 1,020          
2020 1,272          
2021 220          
2022 2,262          
Thereafter 15,913          
Long-term debt of variable interest entities (including current maturities) 1,696 966        
Amount of letters of credit outstanding 6          
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net 167 128        
Variable Interest Entity, Primary Beneficiary [Member]            
VIE Financing            
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net 17          
Letter of Credit            
VIE Financing            
Amount of letters of credit outstanding 498 566        
SCCG            
VIE Financing            
Debt and Lease Obligation         $ 400  
Holdco            
VIE Financing            
Face Amount           $ 100
JSCCG            
VIE Financing            
Face Amount           900
Variable Interest Entity, Primary Beneficiary [Member]            
Liabilities            
Liabilities, Current 79 47        
Other long-term liabilities 14 16        
VIE Financing            
Debt and Lease Obligation   0   $ 800    
Accounts Payable and Accrued Liabilities 1 1        
Liabilities 1,725 960       $ 1,000
Interest Expense 86 $ 46 $ 48      
2018 49          
2019 51          
2020 53          
2021 56          
2022 58          
Thereafter $ 1,431          
JHLLC            
VIE Financing            
Face Amount       $ 80    
v3.25.3
Asset Retirement Obligations Asset Retirement Obligations (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Liabilities Settled [Line Items]      
Increase in ARO liability $ (392)    
Change in estimate [1] (561) $ 132  
Additional obligations   3,136  
Balance [1] 10,414 10,806 $ 7,489
Asset Retirement Obligation, Liabilities Settled [1] 270 257  
Accretion (recorded as regulatory asset) [1] 439 306  
Asset Retirement Obligation, Current 313 283  
Amortization and Depreciation of Decontaminating and Decommissioning Assets 220 188 188
Change in estimate due to closure of coal yards (34) 76  
Change in estimate due to timing of asset retirement activities 27    
Change in estimate due to Gallatin CCR closure   231  
estimate revision of SLR 164    
Increase in CCR post-closure care   32  
Decrease for legacy CCR due to revised acreage assumptions   38  
Change due to study of non-nuclear plant decommissioning obligations 27    
Nuclear      
Liabilities Settled [Line Items]      
Change in estimate 2 (160)  
Additional obligations   0  
Balance 3,976 3,814 3,808
Asset Retirement Obligation, Liabilities Settled 15 4  
Accretion (recorded as regulatory asset) 175 170  
Non-nuclear      
Liabilities Settled [Line Items]      
Change in estimate (563) 292  
Additional obligations   3,136  
Balance 6,438 6,992 $ 3,681
Asset Retirement Obligation, Liabilities Settled 255 253  
Accretion (recorded as regulatory asset) $ 264 $ 136  
[1]
(1) Includes $313 million and $283 million at September 30, 2025 and 2024, respectively, in Current liabilities.
v3.25.3
Other Long-Term Liabilities Other Long-Term Liabilities (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Other Long-Term Liabilities    
Interest rate swaps $ 698 $ 840
Currency swap liabilities 115 116 [1]
Operating Lease, Liability, Noncurrent 63 88
Derivative, Fair Value, Net [Abstract]    
EnergyRight financing obligation (74) (74)
Deferred Revenue, Noncurrent 39 48
Non-current regulatory liabilities 141 83
Total other long-term liabilities 1,606 1,712
Finance Lease, Liability 726  
Deferred Compensation Liability, Current (70) (74)
Current portion of energy prepayment obligations 25 28
Fair value 12 64
Long-term debt of variable interest entities (including current maturities) 1,696 966
Long-term project cost accruals 204 140
Environmental Exit Costs, Costs Accrued to Date 274 226
Deferred Compensation Liability, Classified, Noncurrent 54 50
Other Sundry Liabilities 21  
Environmental Remediation    
Derivative, Fair Value, Net [Abstract]    
Environmental Exit Costs, Costs Accrued to Date   14
Other long-term liabilities    
Other Long-Term Liabilities    
Interest rate swaps 643 792
Currency swap liabilities 108 109
Derivative, Fair Value, Net [Abstract]    
EnergyRight financing obligation (53) (52)
Customer Advances for Construction 61 55
Membership interests of VIE subject to mandatory redemption 25 7
Other 70 81
Accounts payable and accrued liabilities    
Derivative, Fair Value, Net [Abstract]    
EnergyRight financing obligation (13) (13)
Customer Advances for Construction 155 60
Long-term project cost accruals 256  
Environmental Exit Costs, Costs Accrued to Date 52 3
Financial Instruments Subject to Mandatory Redemption, Settlement Terms, Share Value, Amount, Current $ 17 16
Accounts Payable [Member]    
Derivative, Fair Value, Net [Abstract]    
Long-term project cost accruals   $ 124
[1] See Note 16 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.
v3.25.3
Debt and Other Obligations Debt and Other Obligations - General (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2013
Debt Instrument    
Debt ceiling $ 30,000  
Face Amount $ 40 $ 360
PARRS 1998 Series D Bond    
Debt Instrument    
PARRS interest rate after rate reset 2.134%  
Amount of bonds redeemed $ 318  
Amount of redeemable bond issues outstanding $ 256  
PARRS interest rate after rate reset 2.134%  
PARRS 1999 Series A Bond    
Debt Instrument    
PARRS interest rate after rate reset 2.216%  
Amount of bonds redeemed $ 316  
Amount of redeemable bond issues outstanding $ 208  
PARRS interest rate after rate reset 2.216%  
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Secured Debt of VIEs (Details) - USD ($)
Sep. 30, 2025
Oct. 02, 2024
Sep. 30, 2024
Sep. 30, 2013
Aug. 09, 2013
Sep. 30, 2012
Jan. 17, 2012
Variable Interest Entities              
Face Amount $ 40,000,000     $ 360,000,000      
Financial Instruments Subject to Mandatory Redemption, Settlement Terms, Share Value, Amount 18,000,000   $ 19,000,000        
Long-term debt of variable interest entities (including current maturities) 1,696,000,000   966,000,000        
Reported Value Measurement              
Variable Interest Entities              
Financial Instruments Subject to Mandatory Redemption, Settlement Terms, Share Value, Amount 16,000,000   17,000,000        
Long-term debt of variable interest entities (including current maturities) 1,681,000,000   $ 934,000,000        
SCCG              
Variable Interest Entities              
Interest rate         3.846%    
JSCCG              
Variable Interest Entities              
Face Amount           $ 900,000,000  
Interest rate             4.626%
Holdco              
Variable Interest Entities              
Face Amount           $ 100,000,000  
Interest rate             7.10%
Holdco balloon payment upon maturity $ 10,000,000            
JACTG              
Variable Interest Entities              
Face Amount   $ 720,000,000          
Interest rate   5.078%          
JHLLC              
Variable Interest Entities              
Face Amount   $ 80,000,000          
Interest rate 5.74%            
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Secured Notes of SPEs (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2013
Secured notes    
Secured notes $ 40 $ 360
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Short-Term Debt (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Short-Term Debt, Gross [Line Items]    
Short-term Borrowings Gross $ 0 $ 1,168
Weighted average interest rate - discount notes 0.00% 4.76%
Foreign Currency Transaction Gain (Loss), Unrealized $ 59 $ 62
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Put and Call Options (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
PARRS 1998 Series D Bond  
Debt Instrument  
Amount of redeemable bond issues outstanding $ 256
PARRS interest rate prior to rate reset 6.75%
PARRS interest rate after rate reset 2.134%
Amount of bonds redeemed $ 318
PARRS 1999 Series A Bond  
Debt Instrument  
Amount of redeemable bond issues outstanding $ 208
PARRS interest rate prior to rate reset 6.50%
PARRS interest rate after rate reset 2.216%
Amount of bonds redeemed $ 316
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Debt Securities Activity (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Oct. 02, 2024
Sep. 30, 2013
Debt Instrument          
Face Amount $ 40       $ 360
Discount on debt issues (33) $ (9)      
Redemptions/Maturities of variable interest entities 41 35 $ 39    
Redemptions/Maturities of power bonds 1,022 1,022 $ 29    
Total Current maturities of power bonds issued at par 1,370 1,022      
Short-term debt, net of discounts 0 1,167      
Current maturities of long-term debt of variable interest entities issued at par 49 37      
Variable Interest Entity, Primary Beneficiary [Member]          
Debt Instrument          
Debt and Lease Obligation   0   $ 800  
880591EF5 (12.15.20)          
Debt Instrument          
Total Current maturities of power bonds issued at par $ 20 1      
Interest rate 3.77%        
Debt Instrument, Maturity Date Dec. 15, 2025        
880591EF5 (6.15.21)          
Debt Instrument          
Total Current maturities of power bonds issued at par $ 0 21      
Interest rate 3.77%        
Debt Instrument, Maturity Date Jun. 15, 2026        
880591EW8 [Member]          
Debt Instrument          
Total Current maturities of power bonds issued at par $ 0 1,000      
Interest rate 0.75%        
Debt Instrument, Maturity Date May 15, 2025        
880591CJ9          
Debt Instrument          
Total Current maturities of power bonds issued at par $ 1,350 $ 0      
Interest rate 6.75%        
Debt Instrument, Maturity Date Nov. 01, 2025        
Total          
Debt Instrument          
Debt Instrument, Redemption Period, End Date 1,063 1,057      
Percent of par value 100.00%        
Debt of variable interest entities          
Debt Instrument          
Redemptions/Maturities of variable interest entities $ 41 $ 35      
2009 Series B          
Debt Instrument          
Redemptions/Maturities of power bonds 22 22      
2012 Series A          
Debt Instrument          
Redemptions/Maturities of power bonds 0 1,000      
2020 Series A          
Debt Instrument          
Redemptions/Maturities of power bonds 1,000 0      
Total          
Debt Instrument          
Debt Securities Issues $ 4,767 991      
880591EY4          
Debt Instrument          
Interest rate 4.25%        
Debt Instrument, Maturity Date Sep. 15, 2052        
880591EX6          
Debt Instrument          
Interest rate 1.50%        
Debt Instrument, Maturity Date Sep. 15, 2031        
880591EZ1          
Debt Instrument          
Interest rate 3.875%        
Debt Instrument, Maturity Date Mar. 15, 2028        
880591FB3          
Debt Instrument          
Percent of par value 99.109%        
Interest rate 4.375%        
Debt Instrument, Maturity Date Aug. 01, 2034        
Debt Instrument, Issued, Principal $ 0 1,000      
880591FC1          
Debt Instrument          
Percent of par value 98.517%        
Interest rate 5.25%        
Debt Instrument, Maturity Date Feb. 01, 2055        
Debt Instrument, Issued, Principal $ 1,250 0      
880591FD9          
Debt Instrument          
Percent of par value 99.36%        
Interest rate 4.875%        
Debt Instrument, Maturity Date May 15, 2035        
Debt Instrument, Issued, Principal $ 1,500 0      
880591FE7          
Debt Instrument          
Percent of par value 99.593%        
Interest rate 3.875%        
Debt Instrument, Maturity Date Aug. 01, 2030        
Debt Instrument, Issued, Principal $ 1,250 $ 0      
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Debt Outstanding (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Short-term debt    
Short-term debt, net of discounts $ 0 $ 1,167
Current maturities of long-term debt of variable interest entities issued at par 49 37
Total Current maturities of power bonds issued at par 1,370 1,022
Total current debt outstanding, net 1,419 2,226
Long-term debt    
Long-term power bonds, net 20,461 17,867
Long-term power bonds [1] 20,628 17,995
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net (167) (128)
Long-term debt of variable interest entities, net 1,632 897
Total long-term debt, net $ 22,093 18,764
880591DX7    
Short-term debt    
Coupon rate 4.65%  
Debt Instrument, Maturity Date Jun. 15, 2035  
Long-term debt    
Long-term power bonds, net $ 436 436
880591EF5    
Short-term debt    
Coupon rate 3.77%  
Debt Instrument, Maturity Date Jun. 15, 2034  
Long-term debt    
Long-term power bonds, net $ 96 116
880591CJ9    
Short-term debt    
Coupon rate 6.75%  
Debt Instrument, Maturity Date Nov. 01, 2025  
Long-term debt    
Long-term power bonds, net $ 0 1,350
880591EU2 [Member]    
Short-term debt    
Coupon rate 2.875%  
Debt Instrument, Maturity Date Feb. 01, 2027  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591300    
Short-term debt    
Coupon rate 2.134%  
Debt Instrument, Maturity Date Jun. 01, 2028  
Long-term debt    
Long-term power bonds, net $ 256 256
880591409    
Short-term debt    
Coupon rate 2.216%  
Debt Instrument, Maturity Date May 01, 2029  
Long-term debt    
Long-term power bonds, net $ 208 208
880591DM1    
Short-term debt    
Coupon rate 7.125%  
Debt Instrument, Maturity Date May 01, 2030  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591DV1    
Short-term debt    
Coupon rate 4.70%  
Debt Instrument, Maturity Date Jul. 15, 2033  
Long-term debt    
Long-term power bonds, net $ 472 472
880591DP4    
Short-term debt    
Coupon rate 6.587%  
Debt Instrument, Maturity Date Jun. 07, 2032  
Long-term debt    
Long-term power bonds, net $ 337 335
880591CK6    
Short-term debt    
Coupon rate 5.98%  
Debt Instrument, Maturity Date Apr. 01, 2036  
Long-term debt    
Long-term power bonds, net $ 121 121
880591CS9    
Short-term debt    
Coupon rate 5.88%  
Debt Instrument, Maturity Date Apr. 01, 2036  
Long-term debt    
Long-term power bonds, net $ 1,500 1,500
880591CP5    
Short-term debt    
Coupon rate 6.15%  
Debt Instrument, Maturity Date Jan. 15, 2038  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591ED0    
Short-term debt    
Coupon rate 5.50%  
Debt Instrument, Maturity Date Jun. 15, 2038  
Long-term debt    
Long-term power bonds, net $ 500 500
880591EH1    
Short-term debt    
Coupon rate 5.25%  
Debt Instrument, Maturity Date Sep. 15, 2039  
Long-term debt    
Long-term power bonds, net $ 2,000 2,000
880591EP3    
Short-term debt    
Coupon rate 3.50%  
Debt Instrument, Maturity Date Dec. 15, 2042  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591DU3    
Short-term debt    
Coupon rate 4.962%  
Debt Instrument, Maturity Date Jun. 07, 2043  
Long-term debt    
Long-term power bonds, net $ 202 201
880591EB4    
Short-term debt    
Coupon rate 4.875%  
Debt Instrument, Maturity Date Jan. 15, 2048  
Long-term debt    
Long-term power bonds, net $ 500 500
880591DZ2    
Short-term debt    
Coupon rate 5.375%  
Debt Instrument, Maturity Date Apr. 01, 2056  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591EJ7    
Short-term debt    
Coupon rate 4.625%  
Debt Instrument, Maturity Date Sep. 15, 2060  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591ES7    
Short-term debt    
Coupon rate 4.25%  
Debt Instrument, Maturity Date Sep. 15, 2065  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591EX6    
Short-term debt    
Coupon rate 1.50%  
Debt Instrument, Maturity Date Sep. 15, 2031  
Long-term debt    
Long-term power bonds, net $ 500 500
880591EY4    
Short-term debt    
Coupon rate 4.25%  
Debt Instrument, Maturity Date Sep. 15, 2052  
Long-term debt    
Long-term power bonds, net $ 500 500
880591EZ1    
Short-term debt    
Coupon rate 3.875%  
Debt Instrument, Maturity Date Mar. 15, 2028  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591FB3    
Short-term debt    
Coupon rate 4.375%  
Debt Instrument, Maturity Date Aug. 01, 2034  
Long-term debt    
Long-term power bonds, net $ 1,000 1,000
880591FE7    
Short-term debt    
Coupon rate 3.875%  
Debt Instrument, Maturity Date Aug. 01, 2030  
Long-term debt    
Long-term power bonds, net $ 1,250 0
880591FD9    
Short-term debt    
Coupon rate 4.875%  
Debt Instrument, Maturity Date May 15, 2035  
Long-term debt    
Long-term power bonds, net $ 1,500 0
880591FC1    
Short-term debt    
Coupon rate 5.25%  
Debt Instrument, Maturity Date Feb. 01, 2055  
Long-term debt    
Long-term power bonds, net $ 1,250 $ 0
[1] nclude total net exchange gain from currency transactions of $59 million and $62 million at September 30, 2025 and 2024
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Maturities Due (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Debt Instrument    
2018 $ 1,370  
2019 1,020  
2020 1,272  
2021 220  
2022 2,262  
Thereafter 15,913  
Total 22,057  
Short-Term Debt 0 $ 1,167
Net discount on sale of Bonds 113  
Foreign Currency Transaction Gain (Loss), Unrealized 59 $ 62
Power bonds    
Debt Instrument    
Debt issuance costs $ 54  
v3.25.3
Debt and Other Obligations Debt and Other Obligations - Credit Facility Agreements (Details)
Sep. 30, 2025
USD ($)
Credit_facilities
Sep. 30, 2024
USD ($)
Credit Facility Agreements    
Amount of letters of credit outstanding $ 6,000,000  
Borrowings under U.S. Treasury credit facility 0  
Revolving Credit Facilities    
Credit Facility Agreements    
Current borrowing capacity 2,650,000,000  
Credit facility agreements borrowings outstanding $ 0  
Number of revolving credit facilities | Credit_facilities 4  
Revolving Credit Facility 4 $ 150,000,000  
Revolving credit facility 1 500,000,000  
Long-term Line of Credit, Borrowings 4 0  
Long-term Line of Credit, Borrowings 1 0  
Line of Credit Facility, Remaining Borrowing Capacity 4 112,000,000  
Line of Credit Facility, Remaining Borrowing Capacity 1 285,000,000  
Long-term Line of Credit, Borrowings 3 0  
Revolving credit facility 3 1,000,000,000  
Line of Credit Facility, Remaining Borrowing Capacity 2,152,000,000  
Line of Credit Facility, Remaining Borrowing Capacity 2 890,000,000  
Long-term Line of Credit, Borrowings 2 0  
Revolving Credit Facility 2 1,000,000,000  
Line of Credit Facility, Remaining Borrowing Capacity 3 true 865,000,000  
Letter of Credit    
Credit Facility Agreements    
Amount of letters of credit outstanding 498,000,000 $ 566,000,000
Letters of Credit Outstanding, Amount 3 135,000,000  
Letters of Credit Outstanding, Amount 4 38,000,000  
Letters of Credit Outstanding, Amount 1 215,000,000  
Letter of Credit Outstanding, Amount 2 110,000,000  
Letters of Credit Outstanding, Total 498,000,000  
Line of Credit    
Credit Facility Agreements    
Current borrowing capacity $ 150,000,000  
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivative Instruments That Receive Hedge Accounting Treatment (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Summary of Derivative Instruments That Receive Hedge Accounting Treatment      
Interest rate swaps $ 698 $ 840  
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred 14    
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, after Tax 3 48 $ 42
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, after Tax 1 $ 25 $ 99
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness, Net $ 0    
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivative Instruments That Do Not Receive Hedge Accounting Treatment (Details)
 12 Months Ended
Sep. 30, 2025
USD ($)
Sep. 30, 2024
USD ($)
Derivative    
Change in Unrealized gains (losses) on Interest Rate Derivatives $ (145,000,000) $ (182,000,000)
Fair value 12,000,000 64,000,000
Interest rate swaps 698,000,000 840,000,000
Interest Rate Swap    
Derivative    
Unrealized gains/losses on derivatives 45,000,000 $ (31,000,000)
Unrealized gains/losses on derivatives $ 0  
Commodity Contract Derivatives    
Derivative    
Number of contracts 53 45
Notional amount 562,000,000 321,000,000
Fair value $ 10,000,000 $ 2,000,000
Commodity Contract under FHP    
Derivative    
Unrealized gains/losses on derivatives $ (93,000,000) $ (295,000,000)
Number of contracts 295 126
Notional amount 300 230
Fair value $ (57,000,000) $ (161,000,000)
Commodity Contract under FHP | Fuel Expense    
Derivative    
Unrealized gains/losses on derivatives 77,000,000 245,000,000
Commodity Contract under FHP | Purchased Power Expense    
Derivative    
Unrealized gains/losses on derivatives 16,000,000 50,000,000
Accounts payable and accrued liabilities | Commodity Contract Derivatives    
Derivative    
Fair value (2,000,000) (3,000,000)
Accounts payable and accrued liabilities | Commodity Contract under FHP    
Derivative    
Fair value $ (57,000,000) $ (99,000,000)
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Mark-to-Market Values of TVA Derivatives (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Derivatives, Fair Value    
Amount of letters of credit outstanding $ 6  
Fair value 12 $ 64
250 million Sterling currency swap    
Derivatives, Fair Value    
Fair value (47) (49)
250 million Sterling currency swap | Other long-term liabilities    
Derivatives, Fair Value    
Fair value (43) (45)
250 million Sterling currency swap | Accounts payable and accrued liabilities    
Derivatives, Fair Value    
Fair value (4) (4)
150 million Sterling currency swap    
Derivatives, Fair Value    
Fair value (68) (67)
150 million Sterling currency swap | Other long-term liabilities    
Derivatives, Fair Value    
Fair value (65) (64)
150 million Sterling currency swap | Accounts payable and accrued liabilities    
Derivatives, Fair Value    
Fair value (3) (3)
$1.0 billion notional interest rate swap    
Derivatives, Fair Value    
Fair value (526) (622)
$1.0 billion notional interest rate swap | Other long-term liabilities    
Derivatives, Fair Value    
Fair value (485) (586)
$1.0 billion notional interest rate swap | Accounts payable and accrued liabilities    
Derivatives, Fair Value    
Fair value (13) (10)
$1.0 billion notional interest rate swap | Interest payable, current    
Derivatives, Fair Value    
Fair value (28) (26)
Commodity contract derivatives    
Derivatives, Fair Value    
Fair value 10 2
Commodity contract derivatives | Other Noncurrent Assets [Member]    
Derivatives, Fair Value    
Fair value 2 2
Commodity contract derivatives | Other long-term liabilities    
Derivatives, Fair Value    
Fair value (4) (2)
Commodity contract derivatives | Other current assets    
Derivatives, Fair Value    
Fair value 14 5
Commodity contract derivatives | Accounts payable and accrued liabilities    
Derivatives, Fair Value    
Fair value (2) (3)
$14 million notional    
Derivatives, Fair Value    
Fair value (172) (218)
$14 million notional | Other long-term liabilities    
Derivatives, Fair Value    
Fair value (158) (206)
$14 million notional | Accounts payable and accrued liabilities    
Derivatives, Fair Value    
Fair value (5) (3)
$14 million notional | Interest payable, current    
Derivatives, Fair Value    
Fair value (9) (9)
Commodity Contract under FHP    
Derivatives, Fair Value    
Derivative Liability, Fair Value, Gross Liability 85 165
Fair value (57) (161)
Commodity Contract under FHP | Other Noncurrent Assets [Member]    
Derivatives, Fair Value    
Fair value 8  
Commodity Contract under FHP | Other long-term liabilities    
Derivatives, Fair Value    
Fair value (8) (62)
Commodity Contract under FHP | Accounts payable and accrued liabilities    
Derivatives, Fair Value    
Fair value $ (57) $ (99)
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Currency Swaps Outstanding (Details)
£ in Millions
Sep. 30, 2025
GBP (£)
250 million Sterling currency swap  
Derivative  
Effective Date of Currency Swap Contract 2001
Associated TVA bond issues currency exposure £ 250
Expiration Date of Swap 2032
Overall effective cost to TVA 6.587%
150 million Sterling currency swap  
Derivative  
Effective Date of Currency Swap Contract 2003
Associated TVA bond issues currency exposure £ 150
Expiration Date of Swap 2043
Overall effective cost to TVA 4.962%
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivatives Under Financial Trading Program (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Derivative    
Unrealized gains (losses) deferred as regulatory liabilities (assets) $ 12 $ 64
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Counterparty Credit Risk (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Customers
Sep. 30, 2024
USD ($)
Customers
Derivative    
Receivables from power sales | $ $ 1,908 $ 1,683
Credit of Customers    
Derivative    
Number of customers that represent the percent of sales | Customers 2 2
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Offsetting of Derivative Assets (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Offsetting Assets [Line Items]    
Amount of letters of credit outstanding $ 6  
Letter of Credit    
Offsetting Assets [Line Items]    
Amount of letters of credit outstanding 498 $ 566
Commodity Contract under FHP    
Offsetting Assets [Line Items]    
Gross Amounts of Recognized Assets, subject to master netting or similar arrangements $ 28 $ 4
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Offsetting of Derivative Liabilities (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Offsetting Liabilities [Line Items]    
Gross Amounts Offset in the Balance Sheet $ 20 $ 4
Amount of letters of credit outstanding 6  
Derivative Liability, Subject to Master Netting Arrangement, after Offset 884 1,122
Derivative Asset, Subject to Master Netting Arrangement, after Offset 24 7
Commodity contract derivatives 16 7
Currency Swap    
Offsetting Liabilities [Line Items]    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 115 116
Commodity Contract under FHP    
Offsetting Liabilities [Line Items]    
Gross Amounts of Recognized Liabilities, subject to master netting or similar arrangements 85 165
Derivative Liability, Subject to Master Netting Arrangement, after Offset 65 161
Derivative Asset, Subject to Master Netting Arrangement, after Offset 8 0
Interest Rate Swap    
Offsetting Liabilities [Line Items]    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 698 840
Commodity Contract Derivatives    
Offsetting Liabilities [Line Items]    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 6 5
Derivative Asset, Subject to Master Netting Arrangement, after Offset 16 7
Letter of Credit    
Offsetting Liabilities [Line Items]    
Amount of letters of credit outstanding $ 498 566
Interest rate swap collateral [Member]    
Offsetting Liabilities [Line Items]    
Amount of letters of credit outstanding   $ 535
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Other Derivative Instruments (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Derivative    
Forward Contract Derivative Asset, at Fair Value $ 16 $ 11
Derivative Liability, Subject to Master Netting Arrangement, after Offset 884 1,122
Fair Value, Inputs, Level 2    
Derivative    
Forward Contract Derivative Asset, at Fair Value $ 16 $ 11
v3.25.3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Collateral (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Derivative    
Amount of letters of credit outstanding $ 6  
Likely collateral obligation increase if downgraded 22  
Derivative Liability, Subject to Master Netting Arrangement, after Offset 884 $ 1,122
Collateralized Securities [Member]    
Derivative    
Collateral obligations 456  
Credit Risk    
Derivative    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 884  
Letter of Credit    
Derivative    
Amount of letters of credit outstanding 498 $ 566
Interest swap collateral    
Derivative    
Amount of letters of credit outstanding $ 442  
v3.25.3
Risk Management Activities and Derivative Transactions Counterparty Credit Risk (Details)
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Derivative    
Two Largest Customer Percentage of Total Operating Revenue 17.00% 17.00%
Moody's, A1 Rating    
Derivative    
Natural Gas Banking Counterparties Credit Rating A1  
Moody's, B1 Rating    
Derivative    
Natural Gas Banking Counterparties Credit Rating B1  
Moody's, A2 Rating    
Derivative    
Banking Counterparties Credit Rating A2  
v3.25.3
Fair Value Measurements - Investments (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
Sep. 30, 2024
USD ($)
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Long-term Investments $ 5,573 $ 4,968
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 10 years  
Fair value of gross plan assets $ 8,837 8,959
Number of readily available quoted exchange prices for the investments 0  
NDT    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Long-term Investments $ 3,700  
ART    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Long-term Investments 1,700  
LTDCP    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Unrealized gains (losses) on investments 1 2
SERP    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Unrealized gains (losses) on investments 3 14
ART    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Unrealized gains (losses) on investments 116 171
Debt and Equity Securities, Unrealized Gain (Loss) 7 36
NDT    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Unrealized gains (losses) on investments 221 324
Debt and Equity Securities, Unrealized Gain (Loss) 10 93
Equity Funds [Member] | NDT    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Commitments, Fair Value Disclosure 361  
Real Estate Funds [Member] | NDT    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Commitments, Fair Value Disclosure 138  
Credit [Member] | NDT    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Commitments, Fair Value Disclosure 117  
Equity | ART    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Commitments, Fair Value Disclosure 145  
Private real estate funds | ART    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Commitments, Fair Value Disclosure 89  
Private Credit [Member] | ART    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Commitments, Fair Value Disclosure 57  
RP    
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items]    
Debt and Equity Securities, Unrealized Gain (Loss) $ 1 $ 1
v3.25.3
Fair Value Measurements - Nonperformance Risk (Details)
$ in Millions
Sep. 30, 2025
USD ($)
Nonperformance Risk  
Derivative credit valuation adjustment, assets $ 1
Derivative credit valuation adjustment, liabilities $ 3
v3.25.3
Fair Value Measurements - Fair Value Measurements (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Fair value $ 12 $ 64
Investments    
Government debt securities 473 457
Corporate debt securities 411 378
Mortgage and asset-backed securities 40 43
Institutional mutual funds 367 342
Forward debt securities contracts - asset 16 11
Cash, Cash Equivalents, and Short-term Investments 274 278
Private equity funds measured at net asset value 875 738
Private real estate measured at net asset value 467 432
Private credit measured at net asset value 278 219
Commingled funds measured at net asset value 1,528 1,300
Total investments 5,573 4,968
Commodity contract derivatives 16 7
Total 5,597 4,975
Liabilities    
Currency swaps 115 116 [1]
Interest rate swaps 698 840
Commodity contract derivatives 6 5
Total 884 1,122
Equity Securities, FV-NI, Noncurrent 844 770
Derivative Liability, Subject to Master Netting Arrangement, after Offset 884 1,122
Derivative Asset, Subject to Master Netting Arrangement, after Offset 24 7
Fair Value Measurement Inputs and Valuation Techniques [Line Items]    
Cash, Cash Equivalents, and Short-term Investments 274 278
Net payables 101 47
Payable, Investment, Purchase 60 78
Government debt securities reclassed 111 95
Commingled funds reclassed   495
Repurchase Agreements 124 174
Commodity Contract under FHP    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Fair value (57) (161)
Liabilities    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 65 161
Derivative Asset, Subject to Master Netting Arrangement, after Offset 8 0
Fair Value, Inputs, Level 1    
Investments    
Government debt securities 423 400
Corporate debt securities 0 0
Mortgage and asset-backed securities 0 0
Institutional mutual funds 367 342
Forward debt securities contracts - asset 0 0
Cash, Cash Equivalents, and Short-term Investments 111 95
Private equity funds measured at net asset value 0 0
Private real estate measured at net asset value 0 0
Private credit measured at net asset value 0 0
Commingled funds measured at net asset value 0 0
Total investments 1,745 1,607
Commodity contract derivatives 0 0
Total 1,745 1,607
Liabilities    
Currency swaps 0 0
Interest rate swaps 0 0
Commodity contract derivatives 0 0
Total 0 0
Equity Securities, FV-NI, Noncurrent 844 770
Fair Value Measurement Inputs and Valuation Techniques [Line Items]    
Cash, Cash Equivalents, and Short-term Investments 111 95
Fair Value, Inputs, Level 1 | Commodity Contract under FHP    
Liabilities    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 0 0
Derivative Asset, Subject to Master Netting Arrangement, after Offset 0  
Fair Value, Inputs, Level 2    
Investments    
Government debt securities 50 57
Corporate debt securities 411 378
Mortgage and asset-backed securities 40 43
Institutional mutual funds 0 0
Forward debt securities contracts - asset 16 11
Cash, Cash Equivalents, and Short-term Investments 163 183
Private equity funds measured at net asset value 0 0
Private real estate measured at net asset value 0 0
Private credit measured at net asset value 0 0
Commingled funds measured at net asset value 0 0
Total investments 680 672
Commodity contract derivatives 16 7
Total 704 679
Liabilities    
Currency swaps 115 116
Interest rate swaps 698 840
Commodity contract derivatives 6 5
Total 884 1,122
Equity Securities, FV-NI, Noncurrent 0 0
Fair Value Measurement Inputs and Valuation Techniques [Line Items]    
Cash, Cash Equivalents, and Short-term Investments 163 183
Fair Value, Inputs, Level 2 | Commodity Contract under FHP    
Liabilities    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 65 161
Derivative Asset, Subject to Master Netting Arrangement, after Offset 8  
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 - asset 0 0
Cash, Cash Equivalents, and Short-term Investments 0 0
Private equity funds measured at net asset value 0 0
Private real estate measured at net asset value 0 0
Private credit measured at net asset value 0 0
Commingled funds measured at net asset value 0 0
Total investments 0 0
Commodity contract derivatives 0 0
Total 0 0
Liabilities    
Currency swaps 0 0
Interest rate swaps 0 0
Commodity contract derivatives 0 0
Total 0 0
Equity Securities, FV-NI, Noncurrent 0 0
Fair Value Measurement Inputs and Valuation Techniques [Line Items]    
Cash, Cash Equivalents, and Short-term Investments 0 0
Fair Value, Inputs, Level 3 | Commodity Contract under FHP    
Liabilities    
Derivative Liability, Subject to Master Netting Arrangement, after Offset 0 $ 0
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 0  
[1] See Note 16 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities.
v3.25.3
Fair Value Measurements - Fair Value Measurements Using Significant Unobservable Inputs (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Fair Value Measurements    
Commodity contract derivatives, assets $ 16 $ 7
Commodity contract derivatives, liabilities 6 5
Fair Value, Inputs, Level 3    
Fair Value Measurements    
Commodity contract derivatives, assets 0 0
Commodity contract derivatives, liabilities $ 0 $ 0
v3.25.3
Fair Value Measurements - Estimated Values of Financial Instruments (Details) - USD ($)
Sep. 30, 2025
Sep. 30, 2024
Estimated Values of Financial Instruments (Level 2 Valuation)    
EnergyRight receivables (including current portion) $ 57,000,000 $ 56,000,000
Financing Receivable, after Allowance for Credit Loss 80,000,000 99,000,000
EnergyRight® financing obligations (including current portion) 74,000,000 74,000,000
Financial Instruments Subject to Mandatory Redemption, Settlement Terms, Share Value, Amount 18,000,000 19,000,000
Long-term outstanding power bonds (including current maturities), net 21,967,000,000 19,416,000,000
Long-term debt of variable interest entities (including current maturities) 1,696,000,000 966,000,000
Portion at Other than Fair Value Measurement [Member]    
Estimated Values of Financial Instruments (Level 2 Valuation)    
EnergyRight receivables (including current portion) 57,000,000 56,000,000
Reported Value Measurement    
Estimated Values of Financial Instruments (Level 2 Valuation)    
Financing Receivable, after Allowance for Credit Loss 86,000,000 105,000,000
EnergyRight® financing obligations (including current portion) 66,000,000 66,000,000
Financial Instruments Subject to Mandatory Redemption, Settlement Terms, Share Value, Amount 16,000,000 17,000,000
Long-term outstanding power bonds (including current maturities), net 21,831,000,000 18,889,000,000
Long-term debt of variable interest entities (including current maturities) $ 1,681,000,000 $ 934,000,000
v3.25.3
Proprietary Capital (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Sep. 30, 2022
Appropriation Investment        
Amount of appropriation investment that was repaid $ 1,000      
Net income (loss) 1,360 $ 1,135 $ 500  
Return on power program appropriation investment (8) (7) (6)  
Net proprietary capital at September 30 $ 18,511 $ 17,161 $ 16,056 $ 15,505
Computed average interest rate payable 3.39% 3.02% 1.99%  
Power Program Appropriation Investment        
Appropriation Investment        
Net income (loss) $ 0 $ 0 $ 0  
Return on power program appropriation investment 0 0 0  
Power Program Retained Earnings        
Appropriation Investment        
Net income (loss) 1,368 1,142 508  
Return on power program appropriation investment (8) (7) 6  
Nonpower Programs Appropriation Investment, Net        
Appropriation Investment        
Net income (loss) (8) (7) (8)  
Return on power program appropriation investment 0 0 0  
Affiliated Entity        
Appropriation Investment        
Return on power program appropriation investment $ (8) $ (7) $ (6)  
v3.25.3
Proprietary Capital - Accumulated Other Comprehensive Income (Loss) (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Accumulated Other Comprehensive Income (Loss)  
Reclassification to earnings from cash flow hedges in the next twelve months $ (14)
v3.25.3
Other Income (Expense), Net Other Income (Expense), Net (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Other Income (Expense), Net      
Interest income $ 52 $ 42 $ 34
External services 28 17 15
Gain (Loss) on Investments 14 23 13
Miscellaneous (2) (11) (1)
Other income (expense), net $ 92 $ 71 $ 61
v3.25.3
Benefit Plans Components of Benefit Plans (Details) - USD ($)
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Sep. 30, 2026
Defined Benefit Plan Disclosure        
Fixed and variable fund annual maximum contribution $ 10,000      
Defined contribution plan contribution amount 124,000,000 $ 116,000,000 $ 105,000,000  
Nonqualified Excess 401(k) Plan 2,000,000 1,000,000 $ 1  
Accounts Payable and Accrued Liabilities, Current 3,299,000,000 $ 2,910,000,000    
Amount of defined benefit plan actuarial gain (loss) from change in demograhic and plan experience 37,000,000      
Actuarial Gain (Loss) from Changes in Mortality Assumptions 5,000,000      
Actuarial Gain (Loss) from pre-Medicare Trend Rate Assumptions 30,000,000      
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate [Abstract]        
Discount rate   5.00% 6.05%  
Amount of defined benefit plan actuarial gain (loss) from change in mortality assumption   $ 46,000,000    
Amount of defined benefit plan actuarial gain (loss) from updated capita claims costs and retiree contributions 18,000,000      
Actuarial Gain (Loss) due to Adoption of a Retiree Persistency Assumption 13,000,000      
Amount of defined benefit plan actuarial gain (loss) from change in demograhic and plan experience 37,000,000      
Accounts payable and accrued liabilities        
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate [Abstract]        
Postemployment Benefits Liability   28,000,000    
Other Post-retirement Benefits        
Defined Benefit Plan Disclosure        
Accounts Payable and Accrued Liabilities, Current $ 17,000,000 $ 20,000,000    
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate [Abstract]        
Discount rate 5.62% 5.00%    
Actuarial Gain (Loss) from Delaying post-Medicare Trend Rate Assumption $ 28,000,000      
Amount of defined benefit plan actuarial gain (loss) from updated capita claims costs and retiree contributions 3,000,000      
Pension Benefits        
Defined Benefit Plan Disclosure        
Accounts Payable and Accrued Liabilities, Current 9,000,000 $ 6,000,000    
Amount of defined benefit plan actuarial gain (loss) from discount rate change 514,000,000 $ 981,000,000    
Amount of defined benefit plan actuarial gain (loss) from change in demograhic and plan experience $ 18,000,000      
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate [Abstract]        
Discount rate 5.47% 4.95% 5.95%  
Amount of defined benefit plan actuarial gain (loss) from change in mortality assumption $ 39,000,000      
Actual Return on Plan Assets 4.90% 12.72% 6.13%  
Amount of defined benefit plan actuarial gain (loss) from change in demograhic and plan experience $ 18,000,000      
Minimum        
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate [Abstract]        
Defined Contribution Plan, Employers Matching Contribution, Annual Vesting Percentage 300.00%      
Defined Contribution Plan, Employer Matching Contribution, Percent of Match 150.00%      
Maximum        
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate [Abstract]        
Defined Contribution Plan, Employers Matching Contribution, Annual Vesting Percentage 600.00%      
Defined Contribution Plan, Employer Matching Contribution, Percent of Match 600.00%      
Minimum        
Defined Benefit Plan Disclosure        
Threshold for Deferral of Actuarial Gain/Loss Under Corridor Approach 10.00%      
Scenario, Forecast | Pension Benefits        
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate [Abstract]        
Defined Benefit Plan, Cost of Living Adjustment Assumption Next Fiscal Year       2.49%
v3.25.3
Benefit Plans Obligations and Funded Status (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Change in benefit obligation      
Actuarial Gain (Loss) from pre-Medicare Trend Rate Assumptions $ 30    
Actuarial Gain (Loss) from Changes in Mortality Assumptions 5    
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]      
Discount rate   5.00% 6.05%
Amount of defined benefit plan actuarial gain (loss) from updated capita claims costs and retiree contributions (18)    
Amount of defined benefit plan actuarial gain (loss) from change in mortality assumption   $ (46)  
Amount of defined benefit plan actuarial gain (loss) from change in demograhic and plan experience 37    
Actuarial Gain (Loss) from Changes in Withdrawal Assumption Rates 2    
Actuarial Gain (Loss) from Observed Plan Experience $ 2    
Percent Funded Status 10000.00%    
Pension Benefits      
Change in benefit obligation      
Benefit obligation $ 11,002 10,099  
Defined Benefit Plan, Pension Plan with Projected Benefit Obligation in Excess of Plan Assets, Projected Benefit Obligation 10,301 11,002  
Service cost 32 29 $ 32
Defined Benefit Plan, Interest Cost 526 579 568
Plan participants' contributions 3 3  
Change in Plan Assets due to Collections 0 0  
Collections [1] 0 0  
Actuarial loss (gain) 457 1,059  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement and Curtailment (1) 0  
Defined Benefit Plan, Cost of Providing Special and Contractual Termination Benefits 0 0 $ 0
Net transfers from variable fund/401(k) plan 2 5  
Expenses paid (7) (6)  
Benefits paid 799 766  
Defined Benefit Plan, Pension Plan with Projected Benefit Obligation in Excess of Plan Assets, Plan Assets 8,594 8,673  
Change in plan assets      
Fair value of net plan assets 8,673 8,129  
Actual return on plan assets 412 1,004  
Employer contributions 310 304  
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]      
Funded status $ (1,707) $ (2,329)  
Discount rate 5.47% 4.95% 5.95%
Amount of defined benefit plan actuarial gain (loss) from discount rate change $ (514) $ (981)  
Amount of defined benefit plan actuarial gain (loss) from change in mortality assumption (39)    
Amount of defined benefit plan actuarial gain (loss) from change in demograhic and plan experience 18    
Other Post-retirement Benefits      
Change in benefit obligation      
Benefit obligation 291 353  
Postconfirmation, Other Postretirement Obligations   347  
Service cost 11 11 $ 10
Defined Benefit Plan, Interest Cost 17 21 18
Plan participants' contributions 0 0  
Change in Plan Assets due to Collections 12 12  
Collections [1] 12 12  
Actuarial loss (gain) 67 4  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement and Curtailment 0 0  
Defined Benefit Plan, Benefit Obligation, Special and Contractual Termination Benefits 1 0  
Defined Benefit Plan, Cost of Providing Special and Contractual Termination Benefits 1 0 $ 0
Net transfers from variable fund/401(k) plan 0 0  
Expenses paid 0 0  
Benefits paid 36 34  
Actuarial Gain (Loss) from Changes in Discount Rate 24 43  
Actuarial Gain (Loss) from Delaying post-Medicare Trend Rate Assumption 28    
Change in plan assets      
Fair value of net plan assets 0 0  
Actual return on plan assets 0 0  
Employer contributions 24 22  
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]      
Funded status $ (291) $ (353)  
Discount rate 5.62% 5.00%  
Amount of defined benefit plan actuarial gain (loss) from updated capita claims costs and retiree contributions $ (3)    
[1] Collections include retiree contributions as well as provider discounts and rebates.
(2) The 2025 pension obligation plan curtailment gain is a result of the amendments to the TVA SERP in which participants ceased accruing new benefits effective September 30, 2025. This reduced the projected benefit obligation by $1 million.
(3) Special/contractual termination benefits for certain eligible employees related to TVA's restructuring activities. For 2025, the other post-retirement plan recognized a loss that increased the obligation by $1 million as a result of special/contractual termination benefits for certain eligible employees related to TVA’s restructuring activities. See Note 3 — Restructuring.
v3.25.3
Benefit Plans Amounts Recognized on TVA's Consolidated Balance Sheets (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Defined Benefit Plan Disclosure      
Regulatory assets $ (8,047) $ (9,408)  
Non-current regulatory liabilities (141) (83)  
Accounts payable and accrued liabilities (3,299) (2,910)  
Pension and post-retirement benefit obligations (2,183) (2,887)  
Postemployment benefits liability, noncurrent 233 258  
Pension Benefits      
Defined Benefit Plan Disclosure      
Regulatory assets (1,531) (1,979)  
Accounts payable and accrued liabilities (9) (6)  
Pension and post-retirement benefit obligations [1] (1,698) (2,323)  
Other Post-retirement Benefits      
Defined Benefit Plan Disclosure      
Regulatory assets (131) (81)  
Non-current regulatory liabilities (131)    
Accounts payable and accrued liabilities (17) (20)  
Pension and post-retirement benefit obligations [1] (274) (333)  
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent      
Defined Benefit Plan Disclosure      
Postemployment benefits liability, noncurrent 208 230 $ 266
Restoration Plan      
Defined Benefit Plan Disclosure      
Postemployment benefits liability, noncurrent $ 3 $ 1  
[1] The table above excludes $208 million of post-employment benefit costs and $3 million of RP costs at September 30, 2025, and $230 million of post-employment benefit costs and $1 million of RP costs at September 30, 2024 that are recorded in Post-retirement and post-employment benefit obligations on the Consolidated Balance Sheets.
v3.25.3
Benefit Plans Postretirement Benefit Costs Deferred as Regulatory Assets (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Defined Benefit Plan Disclosure    
Regulatory assets $ (8,047) $ (9,408)
Non-current regulatory liabilities 141 83
Pension Benefits    
Defined Benefit Plan Disclosure    
Unrecognized prior service cost (credit) (158) (247)
Unrecognized net loss 1,689 2,226
Regulatory assets (1,531) (1,979)
Other Post-retirement Benefits    
Defined Benefit Plan Disclosure    
Unrecognized prior service cost (credit) (25) (42)
Unrecognized net loss (106) (39)
Regulatory assets (131) $ (81)
Non-current regulatory liabilities $ 131  
v3.25.3
Benefit Plans Projected Benefit Obligations and Accumulated Benefit Obligations in Exess of Plan Assets (Details) - Pension Benefits - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Defined Benefit Plan Disclosure    
Accumulated benefit obligation $ 10,278 $ 10,971
Defined Benefit Plan, Pension Plan with Projected Benefit Obligation in Excess of Plan Assets, Plan Assets 8,594 8,673
Fair value of net plan assets $ 8,673 $ 8,129
v3.25.3
Benefit Plans Components of Net Periodic Benefit Cost (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Pension Benefits      
Defined Benefit Plan Disclosure      
Service cost $ 32 $ 29 $ 32
Defined Benefit Plan, Cost of Providing Special and Contractual Termination Benefits 0 0 0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement and Curtailment (1) 0  
Expected return on plan assets 505 494 492
Net periodic benefit cost as acutarially determined 137 124 232
Amount expensed due to actions of regulator 0 0 (77)
Total net period benefit cost 137 124 155
Actuarial loss (gain) 173 99 135
Defined Benefit Plan, Interest Cost 526 579 568
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) (89) (89) (88)
Other Post-retirement Benefits      
Defined Benefit Plan Disclosure      
Service cost 11 11 10
Defined Benefit Plan, Cost of Providing Special and Contractual Termination Benefits 1 0 0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement and Curtailment 0 0  
Expected return on plan assets 0 0 0
Net periodic benefit cost as acutarially determined 11 14 9
Amount expensed due to actions of regulator 0 0 0
Total net period benefit cost 10 14 9
Actuarial loss (gain) (1) 1 2
Defined Benefit Plan, Interest Cost 17 21 18
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) $ (17) $ (17) $ (17)
v3.25.3
Benefit Plans Actuarial Assumptions (Details) - USD ($)
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Sep. 30, 2026
Defined Benefit Plan Disclosure        
Discount rate   5.00% 6.05%  
Defined Benefit Plan, Cost of Living Adjustment Assumption 0.25%      
Pension Benefits        
Defined Benefit Plan Disclosure        
Discount rate 4.95% 5.95% 5.60%  
Discount rate 5.47% 4.95% 5.95%  
Rate of compensation increase 3.97% 4.01%    
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Weighted-Average Interest Crediting Rate 5.11% 5.13%    
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Weighted-Average Interest Crediting Rate 5.11% 5.13% 5.14%  
Expected return on plan assets 6.50% 6.50% 6.50%  
Defined Benefit Plan, Cost of Living Adjustment Assumption 2.00% 2.00% 2.00%  
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase 3.96% 4.01% 3.28%  
COLA percentage increase (decrease) 6.00%      
Actual Return on Plan Assets 4.90% 12.72% 6.13%  
Other Post-retirement Benefits        
Defined Benefit Plan Disclosure        
Discount rate 5.00% 6.05% 5.65%  
Discount rate 5.62% 5.00%    
Defined Benefit Plan, Cost of Living Adjustment Assumption 2.00% 2.00% 2.00%  
Minimum        
Defined Benefit Plan Disclosure        
Rate of compensation increase 3.00%      
Maximum        
Defined Benefit Plan Disclosure        
Rate of compensation increase 5.50%      
Scenario, Forecast | Pension Benefits        
Defined Benefit Plan Disclosure        
Defined Benefit Plan, Cost of Living Adjustment Assumption Next Fiscal Year       2.49%
Post-Medicare Eligible [Member] [Member] | Other Post-retirement Benefits        
Defined Benefit Plan Disclosure        
Current health care cost trend rate 0.00% 0.00% 0.00%  
Ultimate health care cost trend rate 4.00% 4.00% 4.00%  
Year health care cost ultimate trend rate is reached for Net Benefit Cost Assumption 2026 2026 2026  
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate 2029 2026    
Pre-Medicare Eligible per Capita Claim Costs | Other Post-retirement Benefits        
Defined Benefit Plan Disclosure        
Current health care cost trend rate 7.25% 7.50% 7.00%  
Ultimate health care cost trend rate 5.00% 5.00% 5.00%  
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate 2036 2034 2031  
Initial health care cost trend rate $ 0.0775 $ 0.0725    
Defined Benefit Plan, Year ultimate trend rate is reached for net periodic benefit 2034 2034    
Pre-Medicare Eligible per Capita Contributions | Other Post-retirement Benefits        
Defined Benefit Plan Disclosure        
Current health care cost trend rate 7.25% 5.00% 5.00%  
Ultimate health care cost trend rate 5.00% 5.00% 5.00%  
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate 2036 2034    
Initial health care cost trend rate $ 0.0775 $ 0.0725    
Pre-Medicare Eligible per Capita Contributions | Pension Costs [Member]        
Defined Benefit Plan Disclosure        
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate 2034 2022 2022  
v3.25.3
Benefit Plans Sensitivity to Certain Changes in Pension Assumptions (Details) - USD ($)
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Defined Benefit Plan Disclosure      
Defined Benefit Plan, Cost of Living Adjustment Assumption 0.25%    
Discount rate   5.00% 6.05%
Discount rate      
Defined Benefit Plan Disclosure      
Change in Assumption (0.25%)    
Impact on Pension Cost $ 12,000,000    
Impact on Projected Benefit Obligation $ 241,000,000    
Rate of return on plan assets      
Defined Benefit Plan Disclosure      
Change in Assumption (0.25%)    
Impact on Pension Cost $ 19,000,000    
Cost of Living Adjustments [Domain]      
Defined Benefit Plan Disclosure      
Change in Assumption 0.25%    
Impact on Pension Cost $ 20,000,000    
Impact on Projected Benefit Obligation $ 168,000,000    
Other Post-retirement Benefits      
Defined Benefit Plan Disclosure      
Defined Benefit Plan, Cost of Living Adjustment Assumption 2.00% 2.00% 2.00%
Discount rate 5.62% 5.00%  
Actuarial assumption COLA $ 0.0277 $ 0.0444 $ 0.06
Pension Benefits      
Defined Benefit Plan Disclosure      
Defined Benefit Plan, Cost of Living Adjustment Assumption 2.00% 2.00% 2.00%
COLA percentage increase (decrease) 6.00%    
Discount rate 5.47% 4.95% 5.95%
v3.25.3
Benefit Plans Asset Holdings (Details) - USD ($)
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Defined Benefit Plan Disclosure      
Target Allocation 100.00%    
Plan Asset Allocations 100.00% 100.00%  
Growth Assets      
Defined Benefit Plan Disclosure      
Target Allocation 68.00%    
Plan Asset Allocations 59.00% 58.00%  
Defensive growth assets      
Defined Benefit Plan Disclosure      
Target Allocation 20.00%    
Plan Asset Allocations 23.00% 25.00%  
Defensive Assets      
Defined Benefit Plan Disclosure      
Target Allocation 12.00%    
Plan Asset Allocations 18.00% 17.00%  
Other Post-retirement Benefits      
Defined Benefit Plan Disclosure      
Actuarial assumption COLA $ 0.0277 $ 0.0444 $ 0.06
v3.25.3
Benefit Plans Fair Value Measurements (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Years
Sep. 30, 2024
USD ($)
Oct. 01, 2019
USD ($)
Defined Benefit Plan Disclosure      
Fair value of gross plan assets $ 8,837 $ 8,959  
Derivative liabilities   4  
Net payables 101 47  
Payables for collateral on loaned securities $ 142 235  
Voting percentage required to desolve partnership in private equity 80.00%    
Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets $ 1,369 1,396  
Derivative liabilities   1  
Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 1,639 2,161  
Derivative liabilities   3  
Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 24 65 $ 60
Derivative liabilities   0  
Equity securities      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 740 670  
Equity securities | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 727 668  
Equity securities | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Equity securities | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 13 2  
Preferred securities      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 2 3  
Preferred securities | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Preferred securities | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 2  
Preferred securities | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 2 1  
Corporate debt securities      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 770 1,122  
Corporate debt securities | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Corporate debt securities | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 764 1,121  
Corporate debt securities | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 6 1  
Residential mortgage-backed securities      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 523 572  
Residential mortgage-backed securities | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Residential mortgage-backed securities | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 520 511  
Residential mortgage-backed securities | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 3 61  
Debt securities issued by U.S. Treasury and other U.S. government agencies      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 433 543  
Debt securities issued by U.S. Treasury and other U.S. government agencies | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 433 543  
Debt securities issued by U.S. Treasury and other U.S. government agencies | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt securities issued by U.S. Treasury and other U.S. government agencies | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt securities issued by state/local governments      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 17 23  
Debt securities issued by state/local governments | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt securities issued by state/local governments | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 17 23  
Debt securities issued by state/local governments | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt securities issued by foreign governments      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 18 19  
Debt securities issued by foreign governments | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt securities issued by foreign governments | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 18 19  
Debt securities issued by foreign governments | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Equity security commingled funds      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 286 245  
Equity security commingled funds | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Equity security commingled funds | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Equity security commingled funds | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt security commingled funds      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 1,845 1,236  
Debt security commingled funds | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt security commingled funds | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Debt security commingled funds | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Institutional mutual funds      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 196 180  
Institutional mutual funds | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 196 180  
Institutional mutual funds | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Institutional mutual funds | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Cash equivalents and other short-term investments      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 181 249  
Cash equivalents and other short-term investments | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 10 5  
Cash equivalents and other short-term investments | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 171 244  
Cash equivalents and other short-term investments | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private Credit [Member]      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 1,175 1,126  
Private Credit [Member] | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private Credit [Member] | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private Credit [Member] | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private equity funds measured at net asset value      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 1,290 1,580  
Private equity funds measured at net asset value | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private equity funds measured at net asset value | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private equity funds measured at net asset value | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private real estate funds      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 1,209 1,150  
Private real estate funds | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private real estate funds | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Private real estate funds | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Securities lending commingled funds      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 142 235  
Securities lending commingled funds | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Securities lending commingled funds | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 142 235  
Securities lending commingled funds | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Futures      
Defined Benefit Plan Disclosure      
Derivative liabilities 3 1  
Futures | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Derivative liabilities 3 1  
Futures | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Derivative liabilities 0 0  
Futures | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Derivative liabilities 0 0  
Purchased options      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 7 6  
Purchased options | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 0 0  
Purchased options | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets 7 6  
Purchased options | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Fair value of gross plan assets $ 0 0  
Interest Rate Swap      
Defined Benefit Plan Disclosure      
Derivative liabilities   3  
Interest Rate Swap | Fair Value, Inputs, Level 1      
Defined Benefit Plan Disclosure      
Derivative liabilities   0  
Interest Rate Swap | Fair Value, Inputs, Level 2      
Defined Benefit Plan Disclosure      
Derivative liabilities   3  
Interest Rate Swap | Fair Value, Inputs, Level 3      
Defined Benefit Plan Disclosure      
Derivative liabilities   $ 0  
Minimum      
Defined Benefit Plan Disclosure      
Number of years partnerships in private equity generally continue | Years 10    
Number of one year extensions for partnerships in private equity | Years 2    
Maximum      
Defined Benefit Plan Disclosure      
Number of years partnerships in private equity generally continue | Years 14    
Number of one year extensions for partnerships in private equity | Years 3    
v3.25.3
Benefit Plans Fair Value Measurements Using Significant Unobservable Inputs (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Oct. 01, 2019
Defined Benefit Plan Disclosure      
Net payables $ 101 $ 47  
Payables for collateral on loaned securities 142 235  
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation [Roll Forward]      
Fair value of gross plan assets 8,837 8,959  
Fair Value, Inputs, Level 3      
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation [Roll Forward]      
Fair value of gross plan assets 24 65 $ 60
Net realized/unrealized gains 10 2  
Purchases, sales, issuances, and settlements, net (18) 10  
Transfers in and/or out of Level 3 (33) $ (7)  
Fair value of net plan assets $ 24    
v3.25.3
Benefit Plans Estimated Future Benefit Payments (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Pension Benefits    
Defined Benefit Plan Disclosure    
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months $ 827  
Defined Benefit Plan, Expected Future Benefit Payments, Year Two 826  
Defined Benefit Plan, Expected Future Benefit Payments, Year Three 826  
Defined Benefit Plan, Expected Future Benefit Payments, Year Four 819  
Defined Benefit Plan, Expected Future Benefit Payments, Year Five 808  
Defined Benefit Plan, Expected Future Benefit Payment, Five Fiscal Years Thereafter 3,885  
Employer contributions 310 $ 304
Other Post-retirement Benefits    
Defined Benefit Plan Disclosure    
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months 17  
Defined Benefit Plan, Expected Future Benefit Payments, Year Two 17  
Defined Benefit Plan, Expected Future Benefit Payments, Year Three 16  
Defined Benefit Plan, Expected Future Benefit Payments, Year Four 16  
Defined Benefit Plan, Expected Future Benefit Payments, Year Five 16  
Defined Benefit Plan, Expected Future Benefit Payment, Five Fiscal Years Thereafter 93  
Employer contributions 24 $ 22
SERP    
Defined Benefit Plan Disclosure    
Employer contributions $ 9  
v3.25.3
Benefit Plans Contributions (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2026
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Defined Benefit Plan Disclosure        
Defined contribution plan contribution amount   $ 124 $ 116 $ 105
Other postretirement benefit contributions   24 22  
Contribution related to TVARS case   5 5  
Supplemental Employee Retirement Plans, Defined Benefit        
Defined Benefit Plan Disclosure        
Defined Benefit Plan, Related to SERP   10 4  
Other Post-retirement Benefits        
Defined Benefit Plan Disclosure        
Employer contributions   24 22  
Pension Benefits        
Defined Benefit Plan Disclosure        
Employer contributions   310 $ 304  
Other Pension Plans, Defined Benefit        
Defined Benefit Plan Disclosure        
Employer contributions   300    
Minimum | Other Pension Plans, Defined Benefit        
Defined Benefit Plan Disclosure        
Employer contributions   $ 300    
Scenario, Forecast | Other Pension Plans, Defined Benefit        
Defined Benefit Plan Disclosure        
Employer contributions $ 300      
v3.25.3
Benefit Plans Other Postemployment Benefits (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Sep. 30, 2026
Other Post-Employment Benefits        
Discount rate 4.16% 3.81% 4.59%  
Period expense $ 3 $ 21 $ 3  
Postemployment benefits liability, noncurrent 233 258    
Accounts Payable and Accrued Liabilities        
Other Post-Employment Benefits        
Postemployment Benefits Liability, Current 25 28    
Accounts Payable and Accrued Liabilities | Scenario, Forecast        
Other Post-Employment Benefits        
Postemployment Benefits Liability, Current       $ 24
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent        
Other Post-Employment Benefits        
Postemployment benefits liability, noncurrent $ 208 $ 230 $ 266  
v3.25.3
Commitments and Contingencies - Table (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
megawatts
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Obligations      
Megawatts provided under transmission obligations | megawatts 3,750    
Accrual for Environmental Loss Contingencies, Gross $ 8 $ 15  
Estimated future decommissioning cost [1] $ 10,414 10,806 $ 7,489
Remaining terms of the transmission obligations, high end of range 6 years    
Nuclear      
Obligations      
Estimated future decommissioning cost $ 3,976 $ 3,814 $ 3,808
[1]
(1) Includes $313 million and $283 million at September 30, 2025 and 2024, respectively, in Current liabilities.
v3.25.3
Commitments and Contingencies - Membership Interests of VIE Subject to Mandatory Redemption (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Long-term Purchase Commitment [Line Items]    
Financial Instruments Subject to Mandatory Redemption, Settlement Terms, Share Value, Amount $ 18 $ 19
Minimum payments on membership interests subject to mandatory redemption, due in next twelve months 1  
Minimum payments on membership interests subject to mandatory redemption, due in year two 1  
Minimum payments on membership interests subject to mandatory redemption, due in year three 1  
Minimum payments on membership interests subject to mandatory redemption, due in year four 2  
Minimum payments on membership interests subject to mandatory redemption, due in year five $ 2  
v3.25.3
Commitments and Contingencies - Leases (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Leases      
Estimated future decommissioning cost [1] $ 10,414 $ 10,806 $ 7,489
[1]
(1) Includes $313 million and $283 million at September 30, 2025 and 2024, respectively, in Current liabilities.
v3.25.3
Commitments and Contingencies - Purchase Obligations (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
megawatts
Megawatts
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Sep. 30, 2031
USD ($)
Sep. 30, 2030
USD ($)
Sep. 30, 2029
USD ($)
Sep. 30, 2028
USD ($)
Sep. 30, 2027
USD ($)
Sep. 30, 2026
USD ($)
Obligations                  
Megawatts provided under power purchase obligations | Megawatts 5,938                
Remaining terms of the agreements, high end of range 23 years                
Megawatts provided under transmission obligations | megawatts 3,750                
Power purchased under agreement | $ $ 696 $ 519 $ 355            
Scenario, Forecast                  
Obligations                  
Unrecorded Unconditional Purchase Obligation, Including Lease Not yet Commenced, Total | $       $ 242 $ 162 $ 162 $ 162 $ 162 $ 162
Purchase Agreements Required by Federal Law                  
Obligations                  
Megawatts provided under power purchase obligations | Units 281                
Number of generation sources under PPAs | Units 1,344                
v3.25.3
Commitments and Contingencies - Contingencies (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Procedures
Insurance_layers
reactors
Units
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Contingencies      
Nuclear liability insurance $ 500    
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    
Number of licensed nuclear units | Units 7    
Maximum assessment per nuclear incident $ 1,200    
Total amount of protection available $ 16,300    
Number of layers until the U.S. Congress is required to take action | Insurance_layers 2    
Maximum amount of retrospective premiums $ 122    
Maximum idemnity if a covered accident tasks or keeps a nuclear unit offline 490    
Maximum amount of retrospective premiums 50    
Estimated future decommissioning cost [1] $ 10,414 $ 10,806 $ 7,489
Number of procedures for determining estimates for the costs of nuclear decommissioning | Procedures 2    
Estimated liability for cleanup and similar environmental work on a non-discounted basis $ 8 $ 15  
Amount of insurance available for loss at any one site (bottom range) 2,100    
Amount of insurance available for loss at any one site (top range) $ 2,800    
Environmental Remediation      
Contingencies      
Accrual for Environmental Loss Contingencies, Significant Assumptions 319 million 215 million  
Nuclear      
Contingencies      
Estimated future decommissioning cost $ 3,976 $ 3,814 3,808
Non-nuclear      
Contingencies      
Estimated future decommissioning cost $ 6,438 $ 6,992 $ 3,681
[1]
(1) Includes $313 million and $283 million at September 30, 2025 and 2024, respectively, in Current liabilities.
v3.25.3
Commitments and Contingencies - Legal Proceedings (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
Sep. 30, 2024
USD ($)
Legal Proceedings    
Contribution related to TVARS case $ 5 $ 5
Amount remaining to be spent under environmental agreements $ 7  
Megawatts of Cumberland Combined Cycle Plant [Abstract] | Units 1,450  
General    
Legal Proceedings    
Legal loss contingency accrual $ 11  
Environmental Agreements    
Legal Proceedings    
Amount to be invested in certain environmental projects 290  
Amount invested in certain environmental projects 285  
Other long-term liabilities | General    
Legal Proceedings    
Legal loss contingency accrual 9  
Accounts payable and accrued liabilities | General    
Legal Proceedings    
Legal loss contingency accrual $ 2  
v3.25.3
Commitments and Contingencies Unfunded loan commitments (Details)
$ in Millions
Sep. 30, 2025
USD ($)
Other commitments - unfunded loan commitments [Abstract]  
2020 $ 0
v3.25.3
Related Parties Related Parties (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Related Parties      
Other income $ 189 $ 191 $ 166
Long-term Investments 5,573 4,968  
Return on power program appropriation investment (8) (7) (6)
Related Party Transactions      
Related Parties      
Revenue from sales of electricity 132 118 120
Other income 309 273 282
Operating expenses 264 241 234
Additions to property, plant, and equipment 13 12 8
Cash and cash equivalents 31 31 31
Receivables from Customers 89 81 87
Long-term Investments 534 495 391
Receivables, Long-term Contracts or Programs 43 35 38
Accounts payable and accrued liabilities 41 45 42
Long-term power bonds, net 4 3 1
Return on power program appropriation investment $ (8) $ (7) $ (6)
v3.25.3
Unaudited Quarterly Financial Information Unaudited Quarterly Financial Information (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Quarterly Financial Information Disclosure [Abstract]      
Operating expenses $ 11,103 $ 10,086 $ 10,360
Operating income 2,569 2,228 1,694
Net income (loss) $ 1,360 $ 1,135 $ 500
v3.25.3
Revenue (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Electric revenue $ (13,483) $ (12,123) $ (11,888)
Pandemic Relief Credit $ 225    
Revenue from Contract with Customer [Abstract]      
Percent of Pandemic Credit Offered 2.50%    
v3.25.3
Revenue Customer Type (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Electric revenue $ 13,483 $ 12,123 $ 11,888
Bill credits for LTA $ (231) (215) 199
Percentage of total operating revenues 90.20%    
Total number of LPCs | Units 153    
Revenue capitalized during pre-commercial operations $ (4) (3) (3)
Pandemic Relief Credit $ 225    
Number of LPCs signed flexibility agreement | Units 109    
Regulated Operating Revenue $ 13,486 12,128 11,899
Regulated and Unregulated Operating Revenue $ 13,672 $ 12,314 $ 12,054
Percent of sales of electricity to LPCs 91.00% 92.00% 92.00%
MLGW's % of operating revenues 9.00% 9.00% 9.00%
NES's % of operating revenues 8.00% 8.00% 8.00%
Other Operating Segment      
Unregulated Operating Revenue $ (186) $ (186) $ (155)
Off-System Sales      
Unregulated Operating Revenue (7) (8) (14)
Pre-commercial Operations - Capitalized Revenue      
Unregulated Operating Revenue 4 (3) (3)
ALABAMA      
Regulated Operating Revenue 1,995 1,768 1,731
GEORGIA      
Regulated Operating Revenue 329 295 284
KENTUCKY      
Regulated Operating Revenue 850 776 773
MISSISSIPPI      
Regulated Operating Revenue 1,254 1,150 1,146
NORTH CAROLINA      
Regulated Operating Revenue 88 89 89
TENNESSEE      
Regulated Operating Revenue 8,915 7,998 7,819
VIRGINIA      
Regulated Operating Revenue $ 52 47 46
5-year contract arrangement [Member]      
Number of LPCs signed LTA | Units 5    
Percentage of total operating revenues 12.40%    
Revenues $ 1,698    
20-year Termination Notice      
Number of LPCs signed LTA | Units 148    
Percentage of total operating revenues 77.80%    
Revenues $ 10,636    
Federal agencies and other [Member]      
Regulated Operating Revenue 139 125 135
Local Power Company [Member]      
Electric revenue 12,334    
Regulated Operating Revenue 12,334 11,138 10,903
Industries Directly Served [Member]      
Regulated Operating Revenue $ 1,017 $ 868 $ 864
v3.25.3
Revenue Local Power Company Contracts (Details)
$ in Millions
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Electric revenue $ 13,483 $ 12,123 $ 11,888
Total number of LPCs | Units 153    
Percentage of total operating revenues 90.20%    
Percent of wholesale Credit offered 3.10%    
Pandemic Relief Credit $ 225    
Local Power Company [Member]      
Electric revenue $ 12,334    
5-year contract arrangement [Member]      
Number of LPCs signed LTA | Units 5    
Percentage of total operating revenues 12.40%    
v3.25.3
Revenue Economic Development Incentives (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Revenue from Contract with Customer [Abstract]      
Revenues $ 321 $ 318 $ 330
Unpaid economic incentives $ (193) $ (187)  
v3.25.3
Subsequent Events (Details) - USD ($)
$ in Millions
Sep. 30, 2025
Oct. 02, 2024
Sep. 30, 2024
Sep. 30, 2013
Sep. 30, 2012
Debt Instrument, Redemption [Line Items]          
Non-current regulatory liabilities $ 141   $ 83    
Regulatory assets 8,047   9,408    
Face Amount 40     $ 360  
Long-term debt of variable interest entities, net 1,632   897    
Current maturities of long-term debt of variable interest entities issued at par 49   37    
JACTG          
Debt Instrument, Redemption [Line Items]          
Face Amount   $ 720      
Variable Interest Entity, Primary Beneficiary [Member]          
Debt Instrument, Redemption [Line Items]          
Debt and Lease Obligation   $ 800 0    
Holdco          
Debt Instrument, Redemption [Line Items]          
Face Amount         $ 100
Unrealized gains/losses on commodity derivatives          
Debt Instrument, Redemption [Line Items]          
Regulatory assets 12   64    
Unrealized gains/losses on commodity derivatives          
Debt Instrument, Redemption [Line Items]          
Non-current regulatory liabilities $ 10   $ 2    
v3.25.3
Plant Closures (Details) - USD ($)
$ in Millions
 3 Months Ended 12 Months Ended
Sep. 30, 2025
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Completed Plant        
Depreciation   $ 1,900 $ 1,800 $ 1,900
Accumulated depreciation $ 38,716 38,716 $ 38,793  
Cumberland        
Property, Plant and Equipment [Abstract]        
Accelerated depreciation 16 176    
Completed Plant        
Accelerated depreciation 16 176    
Kingston        
Property, Plant and Equipment [Abstract]        
Accelerated depreciation 9 54    
Completed Plant        
Accelerated depreciation $ 9 $ 54    
Property, Plant and Equipment [Member]        
Completed Plant        
Property, Plant and Equipment, Dispositions   15 million 15 million 14 million
v3.25.3
Leases (Details)
 12 Months Ended
Sep. 30, 2025
USD ($)
Units
Sep. 30, 2024
USD ($)
Sep. 30, 2023
USD ($)
Lessee, Lease, Description [Line Items]      
Operating Lease, Right-of-Use Asset $ 113,000,000 $ 149,000,000  
Finance Lease, Right-of-Use-Asset, after Accumulated Amortization 663,000,000 729,000,000  
Total lease assets 776,000,000 878,000,000  
Operating Lease Liability Current 46,000,000 63,000,000  
Current Finance Lease Liability $ 86,000,000 $ 80,000,000  
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration] Other long-term liabilities Other long-term liabilities  
Total lease liabilities $ 835,000,000 $ 931,000,000  
Operating Lease, Cost 73,000,000 77,000,000 $ 69,000,000
Variable Lease, Cost 337,000,000 258,000,000 134,000,000
Short-term Lease, Cost 15,000,000 10,000,000 18,000,000
Finance Lease, Right-of-Use Asset, Amortization 91,000,000 79,000,000 57,000,000
Finance Lease, Interest Expense 46,000,000 37,000,000 43,000,000
Total finance lease costs 137,000,000 116,000,000 100,000,000
Lease, Cost 562,000,000 461,000,000 $ 321,000,000
Operating lease under PPA 75,000,000 121,000,000  
Finance Lease, Liability, Noncurrent 640,000,000 700,000,000  
Leases      
Finance lease under PPA 509,000,000 $ 550,000,000  
Expected Capacity Payments - PPA Leases $ 862,000,000    
Number of PPAs for solar generation and discharge battery energy storage system | Units 3    
Lessee, Finance Lease, Remaining Lease Term 21 years    
v3.25.3
Leases, SoCF (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Lessee, Lease, Description [Line Items]      
Operating cash flows for operating leases $ 72 $ 78 $ 77
Operating cash flows for finance leases 46 37 43
Financing cash flows for finance leases 82 76 56
Lease assets obtained in exchange for lease obligations - finance 28 230 3
Lease assets obtained in exchange for lease obligations - operating $ 14 $ 115 $ 84
v3.25.3
Leases, Weighted Averages (Details)
Sep. 30, 2025
Sep. 30, 2024
Lessee, Lease, Description [Line Items]    
Operating Lease, Weighted Average Remaining Lease Term 3 years 4 years
Finance Lease, Weighted Average Remaining Lease Term 8 years 9 years
Operating Lease, Weighted Average Discount Rate, Percent 4.20% 4.30%
Finance Lease, Weighted Average Discount Rate, Percent 17.00% 17.60%
v3.25.3
Leases, Future Minimum Payments (Details)
$ in Millions
Sep. 30, 2025
USD ($)
Lessee, Lease, Description [Line Items]  
Operating Leases, Future Minimum Payments Due, Next Twelve Months $ 50
Total 116
Operating Leases, Future Minimum Payments, Due in Two Years 35
Present value of future minimum lease payments, operating (7)
Finance Lease, Liability, to be Paid, Year One 144
Finance Lease, Liability, to be Paid, Year Two 142
Finance Lease, Liability, to be Paid, Year Three 137
Finance Lease, Liability, to be Paid, Year Four 134
Finance Lease, Liability, to be Paid, Year Five 133
Finance Lease, Liability, to be Paid, after Year Five 340
Finance Lease, Liability, Payment, Due 1,030
Finance Lease, Liability, Payment Amounts Representing Interest (304)
Finance Lease, Liability 726
Finance present value of net minimum lease payments (109)
Operating Leases, Future Minimum Payments, Due in Three Years 19
Operating Leases, Future Minimum Payments, Due in Four Years 4
Operating Leases, Future Minimum Payments, Due in Five Years 2
Operating Leases, Future Minimum Payments, Due Thereafter $ 6
v3.25.3
Research and Development (Details) - USD ($)
$ in Millions
 12 Months Ended 48 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2026
Research and Development Arrangement, Contract to Perform for Others [Line Items]      
Research and Development Arrangement, Contract to Perform for Others, Costs Incurred, Gross $ 11 $ 41  
Amount of letters of credit outstanding $ 6    
Scenario, Forecast      
Research and Development Arrangement, Contract to Perform for Others [Line Items]      
Other Research and Development Expense     $ 93
v3.25.3
Restructuring and Related Activities (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Restructuring Cost and Reserve [Line Items]    
Increase (Decrease) in Restructuring Reserve $ 40  
Restructuring and Related Cost, Incurred Cost (29)  
Employee Severance    
Restructuring Cost and Reserve [Line Items]    
Restructuring Reserve $ 11 $ 0
v3.25.3
Segment Reporting (Details) - USD ($)
$ in Millions
 12 Months Ended
Sep. 30, 2025
Sep. 30, 2024
Sep. 30, 2023
Segment Reporting [Abstract]      
Segment, Expenditure, Addition to Long-Lived Assets $ 5,000 $ 3,900 $ 3,000