DEI Document
DEI Document shares in Millions, $ in Millions | 12 Months Ended |
Sep. 30, 2019USD ($)shares | |
Document Information [Line Items] | |
Entity Registrant Name | Tennessee Valley Authority |
Entity Central Index Key | 0001376986 |
Current Fiscal Year End Date | --09-30 |
Entity Filer Category | Non-accelerated Filer |
Document Type | 10-K |
Document Period End Date | Sep. 30, 2019 |
Document Fiscal Year Focus | 2019 |
Document Fiscal Period Focus | FY |
Amendment Flag | false |
Entity Common Stock, Shares Outstanding | shares | 0 |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Shell Company | false |
Entity Well-known Seasoned Issuer | No |
Entity Voluntary Filers | No |
Entity Current Reporting Status | Yes |
Entity Public Float | $ | $ 0 |
CONSOLIDATED STATEMENTS OF OPER
CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Operating revenues | |||
Electric revenue | $ 11,159 | $ 11,075 | $ 10,586 |
Other revenue | 159 | 158 | 153 |
Revenue from sales of electricity | 11,318 | 11,233 | 10,739 |
Operating expenses | |||
Fuel | 1,896 | 2,049 | 2,169 |
Purchased power | 1,007 | 973 | 991 |
Operating and maintenance | 3,090 | 2,598 | 2,604 |
Depreciation and amortization | 1,973 | 2,527 | 1,717 |
Tax equivalents | 541 | 518 | 525 |
Total operating expenses | 8,507 | 8,665 | 8,006 |
Operating income | 2,811 | 2,568 | 2,733 |
Other income (expense), net | 62 | 50 | 56 |
Defined Benefit Plan, Other Cost (Credit) | 258 | 256 | 758 |
Interest expense | |||
Interest expense | 1,198 | 1,243 | 1,346 |
Net income (loss) | 1,417 | 1,119 | 685 |
ALABAMA | |||
Operating revenues | |||
Electric revenue | 1,593 | 1,600 | 1,524 |
GEORGIA | |||
Operating revenues | |||
Electric revenue | 270 | 267 | 252 |
KENTUCKY | |||
Operating revenues | |||
Electric revenue | 691 | 696 | 665 |
MISSISSIPPI | |||
Operating revenues | |||
Electric revenue | 1,063 | 1,052 | 1,016 |
NORTH CAROLINA | |||
Operating revenues | |||
Electric revenue | 74 | 66 | 57 |
TENNESSEE | |||
Operating revenues | |||
Electric revenue | 7,419 | 7,350 | 7,041 |
VIRGINIA | |||
Operating revenues | |||
Electric revenue | $ 45 | $ 48 | $ 47 |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Current assets | ||
Cash and cash equivalents | $ 299 | $ 299 |
Accounts receivable, net | 1,739 | 1,657 |
Inventories, net | 999 | 961 |
Regulatory assets | 156 | 414 |
Other current assets | 85 | 86 |
Total current assets | 3,278 | 3,417 |
Property, plant, and equipment | ||
Completed plant | 62,944 | 61,114 |
Less accumulated depreciation | (31,384) | (29,335) |
Net completed plant | 31,560 | 31,779 |
Construction in progress | 1,893 | 1,999 |
Nuclear fuel | 1,534 | 1,487 |
Capital leases | 146 | 149 |
Total property, plant, and equipment, net | 35,133 | 35,414 |
Investment funds | 2,968 | 2,862 |
Regulatory and other long-term assets | ||
Regulatory assets | 8,763 | 6,612 |
Other long-term assets | 325 | 362 |
Total regulatory and other long-term assets | 9,088 | 6,974 |
Total assets | 50,467 | 48,667 |
Current liabilities | ||
Accounts payable and accrued liabilities | 1,812 | 1,982 |
Accrued interest | 296 | 305 |
Current portion of leaseback obligations | 40 | 38 |
Current portion of energy prepayment obligations | 0 | 10 |
Regulatory liabilities | 150 | 187 |
Short-term debt, net of discounts | 922 | 1,216 |
Total Current maturities of power bonds issued at par | 1,030 | 1,032 |
Current maturities of long-term debt of variable interest entities issued at par | 39 | 38 |
Current maturities of notes payable | 23 | 46 |
Total current liabilities | 4,312 | 4,854 |
Other liabilities | ||
Post-retirement and post-employment benefit obligations | 6,181 | 4,476 |
Asset retirement obligations | 5,453 | 4,665 |
Other long-term liabilities | 2,490 | 2,715 |
Leaseback obligations | 223 | 263 |
Non-current regulatory liabilities | 0 | 104 |
Total other liabilities | 14,347 | 12,223 |
Long-term debt, net | ||
Long-term power bonds, net | 19,094 | 20,157 |
Long-term debt of variable interest entities, net | 1,089 | 1,127 |
Long-term notes payable | 0 | 23 |
Total long-term debt, net | 20,183 | 21,307 |
Total liabilities | 38,842 | 38,384 |
Commitments and contingencies (Note 21) | ||
Proprietary capital | ||
Power program appropriation investment | 258 | 258 |
Power program retained earnings | 10,823 | 9,404 |
Total power program proprietary capital | 11,081 | 9,662 |
Nonpower programs appropriation investment, net | 556 | 564 |
Accumulated other comprehensive income (loss) | (12) | 57 |
Total proprietary capital | 11,625 | 10,283 |
Total liabilities and proprietary capital | $ 50,467 | $ 48,667 |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS $ in Millions | 12 Months Ended | ||
Sep. 30, 2019USD ($) | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | |
Regulatory asset amount expensed | $ 261 | $ 2 | $ 143 |
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents | 322 | 322 | |
Cash flows from operating activities | |||
Net income (loss) | 1,417 | 1,119 | 685 |
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) | 1,993 | 2,554 | 1,763 |
Amortization of nuclear fuel cost | 379 | 382 | 341 |
Non-cash retirement benefit expense | 314 | 324 | 837 |
Prepayment credits applied to revenue | (10) | (100) | (100) |
Changes in current assets and liabilities | |||
Accounts receivable, net | (40) | (68) | 230 |
Inventories and other current assets, net | (87) | 65 | 1 |
Accounts payable and accrued liabilities | (155) | 143 | (109) |
Accrued interest | (8) | (36) | (17) |
Pension contributions | (307) | (304) | (805) |
Settlements of asset retirement obligations | (89) | (106) | (123) |
Other, net | 52 | (37) | (118) |
Net cash provided by operating activities | 3,720 | 3,938 | 2,728 |
Cash flows from investing activities | |||
Construction expenditures | (1,700) | (1,759) | (2,153) |
Nuclear fuel expenditures | (474) | (457) | (305) |
Purchases of investments | (48) | (49) | (49) |
Loans and other receivables | |||
Advances | (10) | (12) | (11) |
Repayments | 11 | 4 | 8 |
Other, net | (22) | 4 | (26) |
Net cash used in investing activities | (2,243) | (2,269) | (2,536) |
Long-term debt | |||
Issues of power bonds | 0 | 998 | 999 |
Redemptions and repurchases of power bonds | (1,035) | (1,731) | (1,558) |
Redemptions of notes payable | (46) | (53) | (27) |
Payments on debt of variable interest entities | (38) | (36) | (35) |
Short-term debt issues (redemptions), net | (294) | (782) | 592 |
Payments on leases and leasebacks | (43) | (42) | (136) |
Financing costs, net | 0 | (3) | (4) |
Other, net | (21) | (9) | (22) |
Net cash (used in) provided by financing activities | (1,477) | (1,658) | (191) |
Net change in cash and cash equivalents | 0 | 11 | 1 |
Cash and cash equivalents at beginning of the year | 299 | 311 | 310 |
Cash and cash equivalents at end of the year | $ 299 | $ 299 | $ 311 |
CONSOLIDATED STATEMENTS OF CHAN
CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||
Sep. 30, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Dec. 31, 2017 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Balance at beginning of year | $ 10,283 | $ 9,133 | $ 10,283 | $ 9,133 | $ 8,420 | ||
Net income (loss) | $ 588 | 423 | $ (101) | 288 | 1,417 | 1,119 | 685 |
Total other comprehensive income (loss) | (69) | 36 | 33 | ||||
Return on power program appropriation investment | (6) | (5) | (5) | ||||
Balance at end of year | 11,625 | 10,283 | 11,625 | 10,283 | 9,133 | ||
Power Program Appropriation Investment | |||||||
Balance at beginning of year | 258 | 258 | 258 | 258 | 258 | ||
Net income (loss) | 0 | 0 | 0 | ||||
Total other comprehensive income (loss) | 0 | 0 | 0 | ||||
Return on power program appropriation investment | 0 | 0 | 0 | ||||
Balance at end of year | 258 | 258 | 258 | 258 | 258 | ||
Power Program Retained Earnings | |||||||
Balance at beginning of year | 9,404 | 8,282 | 9,404 | 8,282 | 7,594 | ||
Net income (loss) | 1,425 | 1,127 | 693 | ||||
Total other comprehensive income (loss) | 0 | 0 | 0 | ||||
Return on power program appropriation investment | (6) | (5) | (5) | ||||
Balance at end of year | 10,823 | 9,404 | 10,823 | 9,404 | 8,282 | ||
Nonpower Programs Appropriation Investment, Net | |||||||
Balance at beginning of year | 564 | 572 | 564 | 572 | 580 | ||
Net income (loss) | (8) | (8) | (8) | ||||
Total other comprehensive income (loss) | 0 | 0 | 0 | ||||
Return on power program appropriation investment | 0 | 0 | 0 | ||||
Balance at end of year | 556 | 564 | 556 | 564 | 572 | ||
Accumulated Other Comprehensive Income (Loss) Net Gains (Losses) on Cash Flow Hedges | |||||||
Balance at beginning of year | $ 57 | $ 21 | 57 | 21 | (12) | ||
Net income (loss) | 0 | 0 | 0 | ||||
Total other comprehensive income (loss) | (69) | 36 | 33 | ||||
Return on power program appropriation investment | 0 | 0 | 0 | ||||
Balance at end of year | $ (12) | $ 57 | $ (12) | $ 57 | $ 21 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) Statement - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Statement of Comprehensive Income [Abstract] | |||
Net income (loss) | $ 1,417 | $ 1,119 | $ 685 |
Net unrealized gain (loss) on cash flow hedges | (114) | 10 | 59 |
Reclassification to earnings from cash flow hedges | 45 | (26) | 26 |
Total other comprehensive income (loss) | (69) | 36 | 33 |
Total comprehensive income (loss) | $ 1,348 | $ 1,155 | $ 718 |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 12 Months Ended |
Sep. 30, 2019 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | 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 nearly 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. 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 of Directors (the "TVA Board") as authorized by the Tennessee Valley Authority Act of 1933 (the "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 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 business. TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment with the 2014 payment; therefore, this item 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 ( 2019 , 2018 , 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 any of the other factors described above cease to be applicable, TVA would no longer be considered to be a regulated entity and would be required to write off these costs. All regulatory asset write offs would be required to be recognized in earnings in the period in which future recovery ceases to be probable. Basis of Presentation The accompanying consolidated financial statements, which have been prepared in accordance with GAAP, include the accounts of TVA, wholly-owned direct subsidiaries, and variable interest entities ("VIE") of which TVA is the primary beneficiary. See Note 9 — Asset Acquisitions and Note 10 — 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. Reclassifications Certain historical amounts have been reclassified in the accompanying consolidated financial statements to the current presentation. TVA reclassified $ 256 million and $ 758 million of net periodic benefit costs from Operating and maintenance expense to Other net periodic benefit cost in the Consolidated Statements of Operations for the years ending September 30, 2018 and 2017 , respectively, as a result of the retrospective presentation of financing costs due to the implementation of the new accounting standard for defined benefit plan costs effective for TVA October 1, 2018. TVA also reclassified $13 million from Restricted cash and cash equivalents to Other long-term assets on the Consolidated Balance Sheet at September 30, 2018. In the September 30, 2018 , Consolidated Statements of Cash Flows, amounts previously reported as $(30) million Fuel cost adjustment deferral, $(7) million Fuel cost tax equivalents, and $39 million Other, net were consolidated and presented as $2 million Other regulatory amortization and deferrals. Additionally, $(22) million in cash flows from operating activities previously recorded as $(9) million Accounts payable and accrued liabilities and $(13) million Regulatory asset costs were reclassified to Other, net. In cash flows from financing activities, $(5) million previously recorded as Payments to U.S. Treasury was reclassified to Other, net. In the September 30, 2017 , Consolidated Statements of Cash Flows, amounts previously reported as $98 million Fuel cost adjustment deferral, $5 million Fuel cost tax equivalents, and $40 million Other, net were consolidated and presented as $143 million Other regulatory amortization and deferrals. Additionally, $(60) million in cash flows from operating activities previously recorded as $(10) million Accounts payable and accrued liabilities and $(50) million Regulatory asset costs were reclassified to Other, net. In cash flows from financing activities, $(5) million previously recorded as Payments to U.S. Treasury was reclassified to Other, net. Additionally, as a result of the implementation of the new accounting standard for Statement of Cash Flows - Classification of Certain Cash Receipts and Cash Payments, $(29) million and $(9) million were reclassified from Short-term debt issues (redemptions), net in cash flows from financing to Other, net in cash flows from operating activities in 2018 and 2017, respectively. 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 includes 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 22 — Commitments and Contingencies — Legal Proceedings — Environmental Agreements . The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported in the Consolidated Balance Sheets and Consolidated Statements of Cash Flows: Cash, Cash Equivalents, and Restricted Cash At September 30 2019 2018 Cash and cash equivalents $ 299 $ 299 Restricted cash and cash equivalents, included in Other long-term assets 23 23 Total Cash, cash equivalents, and restricted cash $ 322 $ 322 On the September 30, 2018 and 2017, Consolidated Statements of Cash Flows, transfers between cash and restricted cash were previously reported as $12 million and $1 million , respectively, as Other, net in cash flows from operating activities. Due to the implementation of the new accounting standard for restricted cash in 2019, these amounts are not reported as cash flow activities on the Consolidated Statement of Cash Flows. Allowance for Uncollectible Accounts The allowance for uncollectible accounts reflects TVA's estimate of probable losses inherent in its accounts and loans receivable balances excluding the EnergyRight ® loans receivable. TVA determines the allowance based on known accounts, historical experience, and other currently available information including events such as customer bankruptcy and/or customers failing to fulfill payment arrangements after 90 days . It also reflects TVA's corporate credit department's assessment of the financial condition of customers and the credit quality of the receivables. The allowance for uncollectible accounts was less than $1 million at both September 30, 2019 and 2018 , for accounts receivable. Additionally, loans receivable of $131 million and $ 138 million at September 30, 2019 and 2018 , respectively, are included in Accounts receivable, net and Other long-term assets, for the current and long-term portions, respectively, and are reported net of allowances for uncollectible accounts of less than $ 1 million at both September 30, 2019 and 2018 , respectively. 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 are recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income (expense), net. 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 revenue from such pre-commercial generation based on the guidance provided by Federal Energy Regulatory Commission ("FERC") regulations. Watts Bar Nuclear Plant ("Watts Bar") Unit 2 commenced pre-commercial plant operations in June 2016, and commercial operations began in October 2016. In addition, the Paradise Combined Cycle Plant ("Paradise CC") commenced pre-commercial plant operations in October 2016, and commercial operations began in April 2017. The Allen Combined Cycle Plant ("Allen CC") began pre-commercial plant operations in September 2017, and began commercial operations in April 2018. Cogeneration capability at Johnsonville Combustion Turbine Unit 20 commenced pre-commercial plant operations in September 2017, and was placed in service during December 2017. Estimated revenue of $ 11 million related to these projects was capitalized to offset project costs for the year ended September 30, 2018 . TVA also capitalized related fuel costs for these construction projects of approximately $ 19 million during the year ended September 30, 2018 . No such amounts were capitalized during 2019 . 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 Credits. 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 fair value approach. RECs created through TVA-owned asset generation are recorded at zero cost. Emission Allowances . TVA has emission allowances for sulfur dioxide ("SO 2 ") and nitrogen oxide ("NO x ") which are accounted for as inventory. The cost of specific allowances used each month is charged to operating expense based on tons of SO 2 and NO x emitted during the respective compliance periods. Allowances granted to TVA by the Environmental Protection Agency ("EPA") are recorded at zero cost. 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. In 2018, TVA started moving from a site-specific inventory management policy to a fleet-wide strategy 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. 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. 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. 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. 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 the external depreciation studies. These studies will be updated at least every five years. Depreciation expense for the years ended September 30, 2019 , 2018 , and 2017 was $1.8 billion , $ 1.3 billion , and $ 1.3 billion , respectively. Depreciation expense expressed as a percentage of the average annual depreciable completed plant was 3.09 percent for 2019 , 2.45 percent for 2018 , and 2.49 percent for 2017 . Average depreciation rates by asset class are as follows: Property, Plant, and Equipment Depreciation Rates At September 30 2019 2018 2017 Asset Class Nuclear 2.38 2.64 2.66 Coal-fired (1) 4.96 2.32 2.33 Hydroelectric 1.61 1.57 1.58 Gas and oil-fired 3.00 2.93 3.27 Transmission 1.34 1.32 1.34 Other 7.16 5.90 6.12 Note (1) The rate for 2019 includes the acceleration of depreciation related to retiring certain coal-fired units. Coal-Fired . As a result of TVA's decision to idle or retire certain units since the previous depreciation study, TVA recognized $566 million , $ 48 million , and $ 104 million in accelerated depreciation expense related to the units during the years ended September 30, 2019 , 2018 , and 2017 , respectively. Accelerated depreciation is based on the remaining useful life of the asset at the time the decision is made to idle or retire a unit. Capital Lease Agreements. Assets recorded under capital lease agreements are included in property, plant, and equipment. These primarily consist of a natural gas lateral pipeline, power production facilities, water treatment assets, certain office equipment, and land of $ 146 million and $ 149 million at September 30, 2019 and 2018 , respectively. Amortization expense related to capital leases is included in Depreciation and amortization in TVA's statement of operations, excluding leases and other financing obligations where regulatory accounting is applied. See Note 8 — Regulatory Assets and Liabilities — Other Non-Current Regulatory Assets — Deferred Capital Leases and Other Financing Obligations. Reacquired Rights . Property, plant, and equipment includes intangible reacquired rights, net of amortization, of $200 million and $208 million as of September 30, 2019 and 2018 , respectively, related to the purchase of residual interests from lease/leaseback agreements of certain combustion turbine units. Amortization expense was $8 million , $8 million , and $4 million for 2019 , 2018 , and 2017 , respectively. See Note 9 — Asset Acquisitions . Software Costs. 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 . At September 30, 2019 and 2018 , unamortized computer software costs totaled $ 63 million and $ 53 million , respectively. Amortization expense related to capitalized computer software costs was $ 38 million , $32 million , and $26 million for 2019 , 2018 , and 2017 , respectively. Software costs that do not meet capitalization criteria are expensed as incurred. 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. See Note 6 — Plant Closures . 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. These other property-related assets include, but are not limited to, easements and coal rights. Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site restoration. Revisions to the estimates of asset retirement obligations ("AROs") are made whenever factors indicate that the timing or amounts of estimated cash flows have changed materially. Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset. See Note 8 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs and Note 12 — Asset Retirement Obligations. Blended Low-Enriched Uranium Program Under the blended low-enriched uranium ("BLEU") program, TVA, the U.S. Department of Energy ("DOE") , and certain nuclear fuel contractors have entered into agreements providing for the DOE's surplus of enriched uranium to be blended with other uranium down to a level that allows the blended uranium to be fabricated into fuel that can be used in nuclear power plants. Under the terms of an interagency agreement between TVA and the DOE, in exchange for supplying highly enriched uranium materials to the appropriate third-party fuel processors for processing into usable BLEU fuel for TVA, the DOE participates to a degree in the savings generated by TVA's use of this blended nuclear fuel. TVA accrues an obligation with each BLEU reload batch related to the portion of the ultimate future payments estimated to be attributable to the BLEU fuel currently in use. TVA estimated DOE's portion of the cost savings from the program to be $ 166 million since 2006. The last reload of BLEU material is currently underway at Browns Ferry Nuclear Plant ("Browns Ferry") . Since 2011, total payments to the DOE amounted to approximately $ 165 million for this program. No payments were made during the year ended September 30, 2019 , and the remaining obligation recorded was $ 1 million at September 30, 2019 . Down-blend Offering for Tritium TVA, the DOE, and certain nuclear fuel contractors have entered into agreements, referred to as the Down-blend offering for Tritium, that provide for the production, processing, and storage of low-enriched uranium that is to be made using surplus DOE highly enriched uranium and other uranium. Low-enriched uranium can be fabricated into fuel for use in a nuclear power plant. Production of the low-enriched uranium began in the summer of 2019 and is contracted to continue through October 2027. Beginning October 2027, contract activity will consist of storage and flag management. Flag management ensures that the uranium is of U.S. origin, free from foreign obligations, and unencumbered by policy restrictions, so that it can be used in connection with the production of tritium. Under the terms of the interagency agreement between the DOE and TVA, the DOE will reimburse TVA for a portion of the costs of converting the highly enriched uranium to low-enriched uranium. During the year ended September 30, 2019 , TVA received $23 million in reimbursements from the DOE. At September 30, 2019 , TVA recorded $6 million in Accounts receivable, net related to this agreement. Investment Funds Investment funds consist primarily of trust funds designated to fund decommissioning requirements (see Note 22 — Commitments and Contingencies — Decommissioning Costs ), the Supplemental Executive Retirement Plan ("SERP") (see Note 21 — Overview of Plans and Benefits — Supplemental Executive Retirement Plan ), and the Deferred Compensation Plan ("DCP") . 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, and DCP 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, and DCP funds are all classified as trading. Energy Prepayment Obligations In 2004, TVA and its largest customer, Memphis Light, Gas and Water Division ("MLGW") , entered into an energy prepayment agreement under which MLGW prepaid TVA $ 1.5 billion for the future costs of electricity to be delivered by TVA to MLGW over a period of 180 months . TVA accounted for the prepayment as unearned revenue and reported the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2018 Consolidated Balance Sheet. The arrangement ceased in 2019. Revenue was recognized in each year of the arrangement as electricity was delivered to MLGW based on the ratio of units of kilowatt hours delivered to total units of kilowatt hours under contract. As of September 30, 2019 , $ 1.5 billion had been recognized as non-cash revenue on a cumulative basis during the life of the agreement, $10 million and $100 million of which was recognized as non-cash revenue during 2019 and 2018 , respectively. Discounts to account for the time value of money, which are recorded as a reduction to electricity sales, amounted to $ 4 million and $ 46 million for the years ended September 30, 2019 and 2018 , respectively. Insurance Although TVA uses private companies to administer its healthcare plans for eligible active and retired employees not covered by Medicare, TVA does not purchase health insurance. Third-party actuarial specialists assist TVA in determining certain liabilities for self-insured claims. TVA recovers the costs of claims through power rates and through adjustments to the participants' contributions to their benefit plans. These liabilities are included in Other liabilities on the Consolidated Balance Sheets. TVA sponsors an Owner Controlled Insurance Program which provides workers' compensation and liability insurance for a select group of contractors performing maintenance, modifications, outage, and new construction activities at TVA facilities. The Federal Employees' Compensation Act ("FECA") governs liability to employees for service-connected injuries. TVA purchases excess workers' compensation insurance above a self-insured retention. In addition to excess workers' compensation insurance, TVA purchases the following types of insurance: • Nuclear liability insurance; nuclear property, decommissioning, and decontamination insurance; and nuclear accidental outage insurance. See Note 22 — Commitments and Contingencies — Nuclear Insurance . • Excess liability insurance for aviation, auto, marine, and general liability exposures. • Property insurance for certain conventional (non-nuclear) assets. The insurance policies are subject to the terms and conditions of the specific policy, including deductibles or self-insured retentions. To the extent insurance would not provide either a partial or total recovery of the costs associated with a loss, TVA would have to recover any such costs through other means, including through power rates. 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 (clean energy, renewables, distributed resources, and energy efficiency), 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 in the Consolidated Statements of Operations as they are incurred except for the recording of certain regulatory assets for retirement and removal costs. |
Impact of New Accounting Standa
Impact of New Accounting Standards and Interpretations | 12 Months Ended |
Sep. 30, 2019 | |
Accounting Changes and Error Corrections [Abstract] | |
Impact of New Accounting Standards and Interpretations | The following are accounting standard updates issued by the Financial Accounting Standards Board ("FASB") that TVA adopted during 2019 : Defined Benefit Costs Description This guidance changes how information about defined benefit costs for pension plans and other post-retirement benefit plans is presented in employer financial statements. The guidance requires employers that present a measure of operating income in their statement of income to include only the service cost component of net periodic pension cost and net periodic post-retirement benefit cost in operating expenses (together with other employee compensation costs). The other components of net benefit cost, including amortization of prior service cost/credit and settlement and curtailment effects, are to be included in non-operating expenses. Additionally, the guidance stipulates that only the service cost component of net benefit cost is eligible for capitalization in assets. The guidance requires retrospective presentation of the service and non-service cost components in the Consolidated Statements of Operations. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA adopted this standard on a retrospective basis for the prior periods presented resulting in a reclassification of net periodic benefit costs from Operating and maintenance expense to Other net periodic benefit cost in the Consolidated Statements of Operations of $256 million and $758 million during 2018 and 2017, respectively. There was no impact on the Consolidated Balance Sheets because TVA has historically capitalized only the service cost component, which is consistent with the new guidance. See Note 1 — Summary of Significant Accounting Policies — Reclassifications for additional details. Financial Instruments Description This guidance applies to the recognition and measurement of financial assets and liabilities. The standard requires all equity investments to be measured at fair value with changes in the fair value recognized through net income (other than those accounted for under the equity method of accounting or those that result in consolidation of the investee). The standard also amends presentation requirements related to certain changes in the fair value of a liability and eliminates certain disclosure requirements of significant assumptions for financial instruments measured at amortized cost on the balance sheet. Public entities must apply the amendments by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA currently measures all of its equity investments (other than those that result in the consolidation of the investee) at fair value, with changes in the fair value recognized through net income, unless regulatory accounting is applied. The TVA Board has authorized the use of regulatory accounting for changes in fair value of certain equity investments, and as a result, those changes in fair value are deferred as regulatory assets or liabilities. TVA currently discloses significant assumptions around its estimates of fair value for financial instruments carried at amortized cost on its consolidated balance sheet. The adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows because changes in fair value accounting are recognized through regulatory accounting. Revenue from Contracts with Customers Description This guidance, including subsequent amendments, replaces the existing accounting standard and industry specific guidance for revenue recognition with a five-step model for recognizing and measuring revenue from contracts with customers. The underlying principle of the guidance is to recognize revenue related to the transfer of goods or services to customers at the amount expected to be collected. The objective of the new standard is to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within and across industries. The new standard also requires enhanced disclosures regarding the nature, amount, timing, and uncertainty of revenue and the related cash flows arising from contracts with customers. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA adopted this standard using the modified retrospective method with no material changes to the amount or timing of revenue recognition. In accordance with the modified retrospective method, TVA's previously issued financial statements have not been restated to comply with the new accounting standard. Statement of Cash Flows - Classification of Certain Cash Receipts and Cash Payments Description This standard adds or clarifies guidance on the classification of certain cash receipts and payments on the statement of cash flows as follows: debt prepayment or extinguishment costs, settlement of zero-coupon bonds, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate-owned life insurance policies and bank-owned life insurance policies, distributions received from equity method investees, beneficial interest in securitization transactions, and the application of the predominance principle to separately identifiable cash flows. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA adopted this standard on a retrospective basis for the prior periods presented. The adoption of this standard resulted in a reclassification of certain cash payments of $29 million and $9 million from financing activities to operating activities shown on the Consolidated Statements of Cash Flows for 2018 and 2017, respectively. The changes did not have a material impact on TVA's financial condition and results of operations. See Note 1 — Summary of Significant Accounting Policies — Reclassifications for additional details. Statement of Cash Flows - Restricted Cash Description This guidance requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance does not provide a definition of restricted cash or restricted cash equivalents. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters Adoption of this standard resulted in a change to the beginning-of-period and end-of-period cash and cash equivalents and restricted cash amounts presented on the Consolidated Statements of Cash Flows. Amounts previously reported as Other, net in cash flows from operating activities of transfers from cash and restricted cash are not reported as cash flow activities. See Note 1 — Summary of Significant Accounting Policies — Cash, Cash Equivalents, and Restricted Cash for additional details. TVA applied this standard on a retrospective basis for the prior periods presented. The following accounting standards have been issued but as of September 30, 2019 , were not effective and had not been adopted by TVA: Lease Accounting Description This guidance changes the provisions of recognition in both the lessee and lessor accounting models. The standard requires entities that lease assets ("lessees") to recognize on the balance sheet the assets and liabilities for the rights and obligations created by leases with terms of more than 12 months, while also refining the definition of a lease. In addition, lessees are required to disclose key information about the amount, timing and uncertainty of cash flows arising from leasing arrangements. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee primarily depend on its classification as a finance lease (formerly referred to as capital lease) or operating lease. The standard requires both types of leases to be recognized on the balance sheet. Operating leases will result in straight-line expense, while finance leases will result in recognition of interest expense on the lease liability separate from amortization expense. The accounting rules for the owner of assets leased by the lessee ("lessor accounting") remain relatively unchanged. The standard allows for certain practical expedients to be elected related to lease term determination, separation of lease and non-lease elements, reassessment of existing leases, and short-term leases. The standard is to be applied using a modified retrospective transition. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2019. Effect on the Financial Statements or Other Significant Matters TVA has completed its evaluation of the impact of adopting this guidance and the changes on its consolidated financial statements and related disclosures. The standard is expected to impact financial position as adoption will increase the amount of assets and liabilities recognized on TVA's Consolidated Balance Sheets approximately $200 million each. The standard is not expected to have a material impact on results of operations or cash flows as expense recognition is intended to be substantially the same as the existing standard. Practical Expedient Description Package of transition practical expedients (for leases commenced prior to adoption date; expedients must be adopted as a package) Do not need to 1) reassess whether any expired or existing contracts are leases or contain leases, 2) reassess the lease classification for any expired or existing leases, and 3) reassess initial direct costs for any existing leases. Short-term lease expedient (elect by class of underlying asset) Elect as an accounting policy to not apply the recognition requirements to short-term leases by asset class. Existing and expired land easements not previously accounted for as leases Elect to not evaluate existing or expired easements under the new guidance and carry forward current accounting treatment. Comparative reporting requirements for initial adoption Elect to apply transition requirements at adoption date, recognize cumulative effect adjustment to retained earnings in period of adoption, and not apply the new requirements to comparative periods, including disclosures. Derivatives and Hedging - Improvements to Accounting for Hedging Activities Description This guidance better aligns an entity's risk management activities and financial reporting for hedging relationships through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedge results. To meet that objective, the amendments expand and refine hedge accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2019. Effect on the Financial Statements or Other Significant Matters TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations, or cash flows. Customer's Accounting for Implementation Costs in a Cloud Arrangement That Is a Service Contract Description This guidance relates to the accounting for a customer's implementation costs in a hosting arrangement that is a service contract. The amendments align the requirements for capitalizing those implementation costs with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software and hosting arrangements that include an internal-use software license. The amendments also provide requirements for the classification of the capitalized costs and related expense and cash flows in the financial statements, the application of impairment guidance to the capitalized costs, and the application of abandonment guidance to the capitalized costs. Entities are required to apply the amendments either retrospectively or prospectively to all implementation costs incurred after the adoption date. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2020. Early adoption is permitted, and TVA plans to adopt this standard October 1, 2019, on a prospective basis. Effect on the Financial Statements or Other Significant Matters TVA does not expect any material impact on TVA's financial condition, results of operations, or cash flows after the adoption of this standard. Financial Instruments - Credit Losses Description This guidance eliminates the probable initial recognition threshold in current GAAP and, instead, requires an allowance to be recorded for all expected credit losses for certain financial assets that are not measured at fair value. The allowance for credit losses is based on historical information, current conditions, and reasonable and supportable forecasts. The new standard also makes revisions to the other than temporary impairment model for available-for-sale debt securities. Disclosures of credit quality indicators in relation to the amortized cost of financing receivables are further disaggregated by year of origination. The standard also provides a transition relief that is optional for all entities. It provides entities an option to irrevocably elect the fair value option, applied on an instrument-by-instrument basis for eligible instruments. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2020. While early adoption is permitted, TVA does not plan to adopt the standard early. Effect on the Financial Statements or Other Significant Matters TVA is evaluating the potential impact of these changes on its consolidated financial statements and related disclosures. Fair Value Measurement Disclosure Description The guidance changes certain disclosure requirements for fair value measurements. It removes certain disclosure requirements, such as the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy; the policy for timing of the transfers between levels; and the valuation processes for Level 3 fair value measurements. Some disclosure requirements are added, such as the change in unrealized gains and losses included in other comprehensive income for recurring Level 3 fair value measurements and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2020. While early adoption is permitted, TVA does not plan to adopt the standard early. Effect on the Financial Statements or Other Significant Matters TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations or cash flows. TVA is evaluating the potential impact on related disclosures. Defined Benefit Plans - Disclosure Requirements Description This guidance applies to all employers that sponsor defined benefit pension or other post-retirement plans and modifies or clarifies the disclosure requirements for those plans. The amendments in this update remove disclosures that no longer are considered cost-beneficial, clarify the specific requirements of disclosures, and add disclosure requirements identified as relevant. Entities are required to apply the amendments retrospectively. Effective Date for TVA The new standard is effective for TVA's annual reporting periods beginning October 1, 2021. While early adoption is permitted, TVA does not plan to adopt the standard early. Effect on the Financial Statements or Other Significant Matters TVA is evaluating the potential impact of these changes on its consolidated financial statements and related disclosures. |
Accounts Receivable, Net
Accounts Receivable, Net | 12 Months Ended |
Sep. 30, 2019 | |
Accounts Receivable, after Allowance for Credit Loss [Abstract] | |
Accounts Receivable, Net | 3 . Accounts Receivable, Net Accounts receivable primarily consist of amounts due from customers for power sales. The table below summarizes the types and amounts of TVA's accounts receivable: Accounts Receivable, Net At September 30 2019 2018 Power receivables $ 1,624 $ 1,570 Other receivables 115 87 Accounts receivable, net (1) $ 1,739 $ 1,657 Note (1) Allowance for uncollectible accounts was less than $1 million at September 30, 2019 and 2018, and therefore is not represented in the table above. |
Inventories, Net
Inventories, Net | 12 Months Ended |
Sep. 30, 2019 | |
Inventory, Net [Abstract] | |
Inventories, Net | 4 . Inventories, Net The table below summarizes the types and amounts of TVA's inventories: Inventories, Net At September 30 2019 2018 Materials and supplies inventory $ 742 $ 725 Fuel inventory 294 266 RECs/Emission allowance inventory, net 16 14 Allowance for inventory obsolescence (53 ) (44 ) Inventories, net $ 999 $ 961 |
Net Completed Plant
Net Completed Plant | 12 Months Ended |
Sep. 30, 2019 | |
Property, Plant and Equipment, Net, by Type [Abstract] | |
Net Completed Plant | 5 . Net Completed Plant Net completed plant consisted of the following: Net Completed Plant At September 30 2019 2018 Cost Accumulated Depreciation Net Cost Accumulated Depreciation Net Coal-fired (1) $ 17,400 $ 12,538 $ 4,862 $ 16,482 $ 11,033 $ 5,449 Gas and oil-fired 6,054 1,562 4,492 5,990 1,459 4,531 Nuclear 25,543 11,656 13,887 25,227 11,310 13,917 Transmission 7,932 3,083 4,849 7,515 3,038 4,477 Hydroelectric 3,163 1,051 2,112 3,087 1,012 2,075 Other electrical plant 1,920 1,110 810 1,881 1,107 774 Intangible software 3 1 2 3 — 3 Multipurpose dams 900 373 527 900 367 533 Other stewardship 29 10 19 29 9 20 Total $ 62,944 $ 31,384 $ 31,560 $ 61,114 $ 29,335 $ 31,779 Note (1) TVA recognized accelerated depreciation as a result of the decision to idle or retire certain units. See Note 6 — Plant Closures . |
Other Long-Term Assets
Other Long-Term Assets | 12 Months Ended |
Sep. 30, 2019 | |
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract] | |
Other Long-Term Assets | Other Long-Term Assets The table below summarizes the types and amounts of TVA's other long-term assets: Other Long-Term Assets At September 30 2019 2018 EnergyRight ® loans receivable $ 81 $ 90 Loans and other long-term receivables, net (1) 125 125 Commodity contract derivative assets (2) — 31 Restricted cash and cash equivalents (1) 23 23 Prepaid capacity payments 19 27 Other 77 66 Total other long-term assets $ 325 $ 362 Notes (1) At September 30, 2018, $13 million and $10 million previously classified as Restricted cash and cash equivalents and Loans and other long-term receivables, net (a component of Other long-term assets), respectively, have been reclassified to Restricted cash and cash equivalents (a component of Other long-term assets). (2) In 2019, these assets are less than $1 million , and therefore are not represented in the table above. In association with the EnergyRight ® Solutions program, 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 has been in default for 180 days or more or that TVA has determined is 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 September 30, 2019 and 2018 , the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was approximately $20 million and $ 22 million , respectively. See Note 11 — Other Long-Term Liabilities for information regarding the associated financing obligation. |
Regulatory Assets and Liabiliti
Regulatory Assets and Liabilities | 12 Months Ended |
Sep. 30, 2019 | |
Regulatory Assets and Liabilities Disclosure [Abstract] | |
Regulatory Assets and Liabilities | Regulatory Assets and 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 2019 2018 Current regulatory assets Unrealized losses on interest rate derivatives $ 89 $ 73 Unrealized losses on commodity derivatives 39 4 Environmental agreements — 3 Gallatin coal combustion residual facilities — 38 Environmental cleanup costs - Kingston ash spill — 266 Fuel cost adjustment receivable 28 30 Total current regulatory assets 156 414 Non-current regulatory assets Deferred pension costs and other post-retirement benefits costs 4,756 3,119 Non-nuclear decommissioning costs 1,741 1,019 Unrealized losses on interest rate derivatives 1,241 692 Nuclear decommissioning costs 868 784 Unrealized losses on commodity derivatives 15 8 Environmental agreements 12 11 Gallatin coal combustion residual facilities — 861 Other non-current regulatory assets 130 118 Total non-current regulatory assets 8,763 6,612 Total regulatory assets $ 8,919 $ 7,026 Current regulatory liabilities Fuel cost adjustment tax equivalents $ 138 $ 146 Unrealized gains on commodity derivatives 12 41 Total current regulatory liabilities 150 187 Non-current regulatory liabilities Deferred other post-retirement benefits cost — 73 Unrealized gains on commodity derivatives — 31 Total non-current regulatory liabilities — 104 Total regulatory liabilities $ 150 $ 291 In 2017, the TVA Board authorized management to accelerate amortization of certain regulatory assets to the extent actual net income in 2018 exceeded the budgeted amount, up to the aggregate amount of those certain regulatory assets. Assets included in this TVA Board action include: deferred nuclear generating units, environmental cleanup costs related to the Kingston ash spill, and nuclear training costs related to the refurbishing and restarting of Browns Ferry Unit 1 and the construction of Watts Bar Unit 2. TVA recorded $ 857 million of accelerated amortization of the Deferred nuclear generating units and Nuclear training costs regulatory assets in 2018. The TVA Board authorized TVA to use the amount included in the 2019 rate action for these two regulatory assets, to the extent needed, to accelerate amortization of the Environmental cleanup costs - Kingston ash spill regulatory asset in 2019. TVA recorded $266 million of accelerated recovery for the Kingston ash spill regulatory asset in 2019. Deferred Pension Costs and Other Post-retirement Benefit Costs . 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 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 recent plan design changes, future contributions are expected to exceed the expense calculated under U.S. GAAP. Accordingly, TVA will discontinue this regulatory accounting practice once all such deferred costs have been recovered, at which time it will recognize pension costs in accordance with U.S. GAAP. 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 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 already set aside in the ART, future earnings on those investment funds, and future cash contributions to the ART and future earnings thereon. For 2019, TVA recovered in rates a portion of its estimated current year non-nuclear decommissioning costs 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. There is not a specified recovery period; therefore, the regulatory asset is classified as long-term consistent with the ART investments and ARO liability. 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 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 Sheet. 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 will be funded through a combination of the NDT, future earnings on the NDT, and, if necessary, additional TVA cash contributions to the NDT and future earnings thereon. See Note 1 — Summary of Significant Accounting Policies — Investment Funds. There is not a specified recovery period; therefore, the regulatory asset is classified as long-term consistent with the NDT investments and ARO liability. Unrealized Gains (Losses) on Commodity Derivatives. Unrealized gains (losses) on coal and natural gas purchase contracts, included as part of unrealized gains (losses) on commodity derivatives, relate to the mark-to-market ("MtM") valuation of coal and natural gas purchase contracts. These contracts qualify as derivative contracts but do not qualify for cash flow hedge accounting treatment. As a result, TVA recognizes the changes in the market value of these derivative contracts as a regulatory liability or asset. This treatment reflects TVA's ability and intent to recover the cost of these commodity contracts 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 expense at the time the fuel is used to generate electricity. These contracts expire at various times through 2020. 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 15 — Risk Management Activities and Derivative Transactions . Environmental Agreements. In conjunction with the Environmental Agreements, TVA recorded certain liabilities totaling $ 360 million ($ 290 million investment in energy efficiency projects, demand response projects, renewable energy projects, and other TVA projects; $ 60 million to be provided to Alabama, Kentucky, North Carolina, and Tennessee to fund environmental projects with preference for projects in the Tennessee River watershed; and $ 10 million in civil penalties). The TVA Board determined that these costs would be collected in customer rates in the future, and, accordingly, the amounts were deferred as a regulatory asset. Through the end of 2019 , $ 279 million has been paid with respect to environmental projects, $ 60 million has been paid to Alabama, Kentucky, North Carolina, and Tennessee, and $ 10 million has been paid with respect to civil penalties. The remaining deferred amounts will be charged to expense and recovered in rates over future periods as payments are made through 2027. Gallatin Coal Combustion Residuals. Based on the August 2017 Order and the assumptions that a new lined facility would be permitted and constructed on the Gallatin site and all existing CCR materials at Gallatin would be moved to this site, TVA estimated the costs of the project to be approximately $ 900 million , which reflected the expected costs of inflation over the duration of the project but was not discounted to a present value amount given the nature of the obligation. At September 30, 2018, $861 million and $38 million were recorded as long-term and short-term regulatory assets, respectively. As a result of the subsequent decision in TVA's favor by the Sixth Circuit, as well as the June 2019 consent order filed in the case brought by TDEC, Gallatin CCR project costs are now recorded in Asset retirement obligations. See Note 12 for additional details. Environmental Cleanup Costs – Kingston Ash Spill . TVA used regulatory accounting treatment to defer all actual costs incurred and expected future costs related to the Kingston Fossil Plant ("Kingston") Ash Spill. The TVA Board approved a plan to amortize these costs over 15 years beginning on October 1, 2009. Insurance proceeds have been recorded as reductions to the regulatory asset and have reduced amounts collected in future rates. Amounts included as a current regulatory asset on TVA's Consolidated Balance Sheets represent the amount to be amortized in the next 12 months . The TVA Board authorized TVA to use the amount included in the 2019 rate action for the Deferred nuclear generating units and Nuclear training costs regulatory assets, to the extent needed, to accelerate amortization of the Environmental cleanup costs - Kingston ash spill regulatory asset in 2019. The remaining balance at September 30, 2018 was recorded as a current asset, and TVA recorded $266 million of accelerated recovery for the Kingston ash spill regulatory asset in 2019. Fuel Cost Adjustment Receivable. The fuel cost adjustment provides a mechanism to alter rates monthly to reflect changing fuel and purchased power costs, including realized gains and losses relating to transactions under TVA's Financial Trading Program ("FTP") . 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. Other Non-Current Regulatory Assets. Other non-current regulatory assets consist of the following: Deferred Capital Leases and Other Financing Obligations . Deferred capital lease and other financing asset costs represent the difference between the FERC's Uniform System of Accounts Prescribed for Public Utilities and Licensees Subject to the Provisions of the Federal Power Act ("Uniform System of Accounts") model balances and the balances under GAAP guidance. Under the Uniform System of Accounts, TVA recognizes the initial capital lease and other financing asset and liability at inception of the lease or other obligation; however, the annual expense under the Uniform System of Accounts is equal to the annual lease or other financing obligation payments, which differs from GAAP treatment. 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 each capital lease or other financing obligation. These costs will be amortized over the respective lease or other financing obligation terms as lease or other financing obligation 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. Prior to 2017, net removal costs were amortized over a recovery period consistent with the depreciable lives of related assets under the most recent depreciation study. In 2017 and thereafter, 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. |
Asset Acquisitions and Business
Asset Acquisitions and Business Combinations (Notes) | 12 Months Ended |
Sep. 30, 2019 | |
Business Combinations and Settlement of Preexisting Relationships [Abstract] | |
Asset Acquisitions and Business Combinations Disclosure | Asset Acquisitions On September 20, 2017, TVA acquired 100 percent of the equity interests in two special purpose entities ("SPEs") designed to administer rent payments TVA makes under certain of its lease/leaseback arrangements. Each entity holds residual interests in four of TVA's peaking combustion turbine units ("CTs") . TVA acquired these entities in order to reacquire the residual interests in eight CTs it had previously granted in the lease/leaseback arrangements. TVA acquired the entities for total cash consideration of $36 million . The fair value of the assets acquired consisted of $110 million of reacquired rights, and the fair value of liabilities assumed consisted of $74 million in notes payable. Reacquired rights are an intangible asset included in TVA's Completed plant balance and are amortized over the estimated useful life of the underlying CTs. Notes payable assumed in the transaction are included in TVA's Short-term debt and require TVA to make semi-annual payments through May 2020. TVA recognized less than $1 million of amortization expense, related to reacquired rights, within TVA's consolidated statements of operations. Transaction costs were not material. TVA determined that its lease/leaseback obligations were preexisting relationships that were effectively settled in the asset acquisitions. TVA settled the preexisting relationships separately from the asset acquisitions, resulting in a loss on extinguishment of the obligations of $3 million . The carrying value of lease/leaseback obligations effectively settled was $71 million , including accrued interest, and the reacquisition price was $74 million , paid in cash, at the acquisition date. |
Variable Interest Entities
Variable Interest Entities | 12 Months Ended |
Sep. 30, 2019 | |
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [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 conduct, 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 7.0 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 conduct, and financial support of SCCG and has determined that it has a direct variable interest in SCCG resulting from risk associated with the value of the Southaven CCF at the end of the lease term. Based on its analysis, TVA has determined that it is the primary beneficiary of SCCG and, as such, is required to account for the VIE on a consolidated basis. Impact on Consolidated Financial Statements The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG as of September 30, 2019 and 2018 , as reflected on the Consolidated Balance Sheets, are as follows: Summary of Impact of VIEs on Consolidated Balance Sheets At September 30 2019 2018 Current liabilities Accrued interest $ 11 $ 11 Accounts payable and accrued liabilities 3 2 Current maturities of long-term debt of variable interest entities 39 38 Total current liabilities 53 51 Other liabilities Other long-term liabilities 25 28 Long-term debt, net Long-term debt of variable interest entities, net 1,089 1,127 Total liabilities $ 1,167 $ 1,206 Interest expense of $ 56 million , $ 58 million , and $ 59 million related to debt of VIEs and membership interests of variable interest entity subject to mandatory redemption is included in the consolidated statements of operations for the years ended September 30, 2019 , 2018 , and 2017 , respectively. 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. |
Other Long-Term Liabilities
Other Long-Term Liabilities | 12 Months Ended |
Sep. 30, 2019 | |
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 for environmental remediation liabilities and liabilities under agreements related to compliance with certain environmental regulations. See Note 12 — Asset Retirement Obligations , Note 15 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Interest Rate Derivatives , and Note 22 — Commitments and Contingencies — Legal Proceedings — Environmental Agreements . The table below summarizes the types and amounts of Other long-term liabilities: Other Long-Term Liabilities At September 30 2019 2018 Interest rate swap liabilities $ 1,676 $ 1,122 Gallatin coal combustion residual facilities liability — 862 Capital lease obligations 182 178 Currency swap liabilities 193 81 EnergyRight® financing obligation 90 102 Paradise pipeline financing obligation (1) 80 80 Accrued long-term service agreements (1) 66 74 Other (1) 203 216 Total other long-term liabilities $ 2,490 $ 2,715 Note (1) Certain amounts have been reclassified to conform with current year presentation. 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 Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets. As of September 30, 2019 and 2018 , the carrying amount of the interest rate swap liabilities reported in Accounts payable and accrued liabilities was approximately $88 million and $77 million , respectively. See Note 15 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Interest Rate Derivative s for information regarding the interest rate swap liabilities. As of September 30, 2019 , Interest rate swap liabilities increased $ 554 million as compared to September 30, 2018, primarily due to significant decreases in market interest rates used to discount future expected net cash flows in mark-to-market valuations. Gallatin Coal Combustion Residual Facilities Liability. As of September 30, 2018, the estimated cost of the potential Gallatin CCR project was $900 million. The current and long-term portions of the resulting obligation were reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA's Consolidated Balance Sheets. As of September 30, 2018, related liabilities of $30 million were recorded in Accounts payable and accrued liabilities. As a result of the subsequent decision in TVA's favor by the Sixth Circuit, as well as the June 2019 consent order filed in the case brought by TDEC, Gallatin CCR project costs are now recorded in Asset retirement obligations. See Note 12 — Asset Retirement Obligations. EnergyRight ® Financing Obligation . TVA purchases certain loans receivable from its LPCs in association with the EnergyRight ® Solutions 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. As of September 30, 2019 and 2018 , the carrying amount of the financing obligation reported in Accounts payable and accrued liabilities was approximately $ 23 million and $ 25 million , respectively. See Note 7 — Other Long-Term Assets for information regarding the associated loans receivable. Paradise Pipeline Financing Obligation. TVA reserves firm pipeline capacity on an approximately 19 mile pipeline owned by Texas Gas, which serves TVA's Paradise CC. The capacity contract contains a lease component due to TVA's exclusive right to use the pipeline. TVA accounts for this lease component as a financing transaction. 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. As of both September 30, 2019 and 2018 , related liabilities of less than $1 million were recorded in Accounts payable and accrued liabilities. Accrued Long-Term Service Agreement. 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 reported in Accounts payable and accrued liabilities and Other long-term liabilities, respectively, on TVA's Consolidated Balance Sheets. As of September 30, 2019 and 2018 , related liabilities of $12 million and $30 million , respectively, were recorded in Accounts payable and accrued liabilities. |
Asset Retirement Obligations
Asset Retirement Obligations | 12 Months Ended |
Sep. 30, 2019 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Asset Retirement Obligations | Asset Retirement Obligations During the year ended September 30, 2019, TVA's total ARO liability increased $ 837 million . To estimate its decommissioning obligation related to its nuclear generating stations, TVA uses a probability-weighted, discounted cash flow model which, on a unit-by-unit basis, considers multiple outcome scenarios that include significant estimations and assumptions. Those assumptions include (1) estimates of the cost of decommissioning, (2) the method of decommissioning and the timing of the related cash flows, (3) the license period of the nuclear plant, considering the probability of license extensions, (4) cost escalation factors, and (5) the credit adjusted risk free rate to measure the obligation at the present value of the future estimated costs. TVA has ascribed probabilities to two different decommissioning methods related to its nuclear decommissioning obligation estimate: the DECON method and the SAFSTOR method. The DECON method requires radioactive contamination to be removed from a site and safely disposed of or decontaminated to a level that permits the site to be released for unrestricted use shortly after it ceases operation. The SAFSTOR method allows nuclear facilities to be placed and maintained in a condition that allows the facilities to be safely stored and subsequently decontaminated to levels that permit release for unrestricted use. TVA bases its nuclear decommissioning estimates on site-specific cost studies. The most recent study was approved and implemented in September 2017. An increase of $ 250 million was recorded to the nuclear AROs as a result of the updates. Site-specific cost studies are updated for each of TVA's nuclear units at least every five years . TVA also has decommissioning obligations related to its non-nuclear generating sites, ash impoundments, transmission substation and distribution assets, and certain general facilities. To estimate its decommissioning obligation related to these assets, TVA uses estimations and assumptions for the amounts and timing of future expenditures and makes judgments concerning whether or not such costs are considered a legal obligation. Those assumptions include (1) estimates of the costs of decommissioning, (2) the method of decommissioning and the timing of the related cash flows, (3) the expected retirement date of each asset, (4) cost escalation factors, and (5) the credit adjusted risk free rate to measure the obligation at the present value of the future estimated costs. TVA bases its decommissioning estimates for each asset on its identified preferred closure method. During 2019 , the revisions in non-nuclear estimates increased $ 50 million for the year ended September 30, 2019 . As a result of recent experience in completing settlements at certain facilities, costs for asbestos abatement activities across TVA's fossil fleet increased $ 114 million . TVA changed the preferred closure method for the Allen West Impoundment from closure-in-place to closure-by-removal, which resulted in a cost increase of $ 33 million . Partially offsetting these increases was a $ 57 million decrease in costs for Paradise closure projects, and a $44 million decrease in costs for the Allen East Impoundment closure project. Additionally, as a result of the decision in TVA's favor by the Sixth Circuit in the lawsuit brought by TSRA and TCWN, as well as the June 2019 consent order filed in the case brought by TDEC, Gallatin discounted cash flows related to CCR closure and post-closure costs of $672 million have been recorded as Asset retirement obligations. The obligation is based upon the assumptions outlined in the consent order, including a new lined facility will be permitted and constructed on the Gallatin site and existing CCR materials in the existing wet ash disposal impoundments at Gallatin will be moved to this new facility over a 20-year period. See Note 22 — Commitments and Contingencies — Legal Proceedings — Lawsuit Brought by TDEC Involving Gallatin Fossil Plant CCR Facilities and Lawsuit Brought by TSRA and TCWN Involving Gallatin Fossil Plant CCR Facilities for additional information. Additionally, during the years ended September 30, 2019 and 2018 , both the nuclear and non-nuclear liabilities were increased by periodic accretion, partially offset by settlement projects that were conducted during these periods. The nuclear and non-nuclear accretion amounts were deferred as regulatory assets. During 2019 , 2018 , and 2017 , $144 million per year of the related regulatory assets were amortized into expense as these amounts were collected in rates. See Note 8 — Regulatory Assets and Liabilities . TVA maintains investment trusts to help fund its decommissioning obligations. See Note 16 — Fair Value Measurements — Investment Funds and Note 22 — Commitments and Contingencies — Decommissioning Costs for a discussion of the trusts' objectives and the current balances of the trusts. Asset Retirement Obligation Activity Nuclear Non-Nuclear Total Balance at September 30, 2017 $ 2,859 $ 1,445 $ 4,304 Settlements — (106 ) (106 ) Revisions in estimate — 430 430 Additional obligations — 1 1 Accretion (recorded to regulatory asset) 130 35 165 Asset disposition — (15 ) (15 ) Balance at September 30, 2018 2,989 1,790 4,779 (1) Settlements (7 ) (82 ) (89 ) Revisions in estimate — 50 50 Additional obligations 18 — 18 Gallatin CCR — 672 672 Accretion (recorded to regulatory asset) 136 50 186 Balance at September 30, 2019 $ 3,136 $ 2,480 $ 5,616 (1) Note (1) The current portions of the ARO liability in the amounts of $ 163 million a nd $ 115 million at September 30, 2019 and 2018 , respectively, are included in Accounts payable and accrued liabilities. |
Debt and Other Obligations
Debt and Other Obligations | 12 Months Ended |
Sep. 30, 2019 | |
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, 2019 , TVA had only two types of Bonds outstanding: power bonds and discount notes. Power bonds have maturities between one 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 rent payments under its leaseback transactions, as well as its scheduled payments under its lease financing arrangements involving John Sevier CCF and Southaven CCF, 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 assets, (3) additional reductions of TVA's capital obligations, and (4) other lawful purposes related to TVA's power program. 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, 2019 , TVA was in compliance with the rate test. See Note 1 — Summary of Significant Accounting Policies — General. 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, 2015, and must next meet the bondholder protection test for the five -year period ending September 30, 2020 . Secured Debt of VIEs On August 9, 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 on August 9, 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 10 — Variable Interest Entities — Southaven VIE . TVA used the proceeds from the transaction primarily to fund the acquisition of the Southaven CCF from SSSL. On January 17, 2012, JSCCG issued secured notes totaling $ 900 million in aggregate principal amount that bear interest at a rate of 4.626 percent . Also on January 17, 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 10 — 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, 2019 and 2018 totaled approximately $1.1 billion and $ 1.2 billion , respectively. Secured Notes On July 20, 2016, TVA acquired two entities, in a business combination, designed to administer rent payments TVA makes under certain of its lease/leaseback arrangements. On September 27, 2000, the entities issued secured notes totaling $255 million that had an interest rate of 7.299 percent and required amortizing semi-annual payments on each March 15 and September 15 with a maturity date of March 15, 2019. In 2016, TVA assumed these secured notes in the acquisition at a fair value of $78 million . The secured notes of the entities, including current maturities, outstanding at September 30, 2018 , totaled approximately $20 million , and are included in Notes payable on TVA's Consolidated Balance Sheet. No such amounts were outstanding at September 30, 2019 . On September 20, 2017, TVA acquired two entities, in an asset acquisition, designed to administer rent payments TVA makes under certain of its lease/leaseback arrangements. On November 14, 2001, the entities issued secured notes totaling $272 million that had an interest rate of 5.572 percent and required amortizing semi-annual payments on each May 1 and November 1 with a maturity date of May 1, 2020. In 2017, TVA assumed these secured notes in the acquisition at a fair value of $74 million . The secured notes of the entities, including current maturities, outstanding at September 30, 2019 , totaled approximately $23 million , and are included in Notes payable on TVA's Consolidated Balance Sheet. See Note 9 — Asset Acquisitions . Short-Term Debt The following table provides information regarding TVA's short-term borrowings: Short-term Borrowings At September 30 2019 2018 2017 Gross amount outstanding - discount notes $ 922 $ 1,217 $ 1,999 Weighted average interest rate - discount notes 2.152 % 2.045 % 1.000 % Put and Call Options Bond issues of $ 357 million held by the public are redeemable in whole or in part, at TVA's option, on call dates through 2020 and at call prices of 100 percent of the principal amount. Nine Bond issues totaling $ 217 million , with maturity dates ranging from 2025 to 2043 , include a "survivor's option," which allows for right of redemption upon the death of a beneficial owner in certain specified circumstances. These Bonds were classified as long-term as of September 30, 2019 . TVA subsequently announced in October 2019 that $217 million of callable bonds will be redeemed at par on November 15, 2019. See Note 25 — Subsequent Events. Additionally, 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 seven times, from an initial rate of 6.750 percent to the current rate of 3.550 percent. In connection with these resets, $ 301 million of the Bonds have been redeemed; therefore, $ 274 million of the Bonds were outstanding at September 30, 2019 . The coupon rate for the 1999 Series A PARRS, which mature in May 2029, has been reset six times, from an initial rate of 6.50 percent to the current rate of 3.360 percent. In connection with these resets, $ 293 million of the Bonds have been redeemed; therefore, $ 232 million of the Bonds were outstanding at September 30, 2019 . 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, 2019 and 2018. Debt Securities Activity For the years ended September 30 2019 2018 Issues 2018 Series A (1) $ — $ 1,000 Discount on debt issues — (2 ) Total $ — $ 998 Redemptions/Maturities (2) Variable interest entities $ 38 $ 36 Notes payable 46 53 electronotes ® 5 52 2013 Series A 1,000 — 2009 Series B 30 29 1997 Series E — 650 2008 Series B — 1,000 Total $ 1,119 $ 1,820 Notes (1) The 2018 Series A bonds were issued at 99.8 percent of par. (2) All redemptions were at 100 percent of par. Debt Outstanding Total debt outstanding at September 30, 2019 and 2018 , consisted of the following: Short-Term Debt At September 30 CUSIP or Other Identifier Maturity Call/(Put) Date Coupon Rate 2019 2018 Short-term debt, net of discounts $ 922 $ 1,216 Current maturities of long-term debt of VIEs issued at par 39 38 Current maturities of notes payable 23 46 Current maturities of power bonds issued at par 880591EQ1 10/15/2018 1.750% — 1,000 880591EF5 12/15/2019 3.770% 1 1 880591EF5 6/15/2020 3.770% 27 29 88059TEL1 11/15/2019 2.650% 1 1 88059TEL1 5/15/2020 2.650% 1 1 880591EV0 3/15/2020 2.250% 1,000 — Total current maturities of power bonds issued at par 1,030 1,032 Total current debt outstanding, net $ 2,014 $ 2,332 Long-Term Debt At September 30 CUSIP or Other Identifier Maturity Coupon Rate Effective Call Date 2019 Par 2018 Par Stock Exchange Listings electronotes ®(2) 5/15/2020 - 2/15/2043 2.375% - 3.625% 2/15/2015 - 2/15/2018 (5) $ 217 $ 221 None 880591EV0 3/15/2020 2.250% — 1,000 New York 880591EL2 2/15/2021 3.875% 1,500 1,500 New York 880591DC3 6/7/2021 5.805% (3) 246 (1) 261 New York, Luxembourg 880591EN8 8/15/2022 1.875% 1,000 1,000 New York 880591ER9 9/15/2024 2.875% 1,000 1,000 New York 880591CJ9 11/1/2025 6.750% 1,350 1,350 New York, Hong Kong, Luxembourg, Singapore 880591EU2 2/1/2027 2.875% 1,000 1,000 New York 880591300 (4) 6/1/2028 3.550% 273 273 New York 880591409 (4) 5/1/2029 3.360% 232 232 New York 880591DM1 5/1/2030 7.125% 1,000 1,000 New York, Luxembourg 880591DP4 6/7/2032 6.587% (3) 307 (1) 326 New York, Luxembourg 880591DV1 7/15/2033 4.700% 472 472 New York, Luxembourg 880591EF5 6/15/2034 3.770% 246 273 None 880591DX7 6/15/2035 4.650% 436 436 New York 880591CK6 4/1/2036 5.980% 121 121 New York 880591CS9 4/1/2036 5.880% 1,500 1,500 New York 880591CP5 1/15/2038 6.150% 1,000 1,000 New York 880591ED0 6/15/2038 5.500% 500 500 New York 880591EH1 9/15/2039 5.250% 2,000 2,000 New York 880591EP3 12/15/2042 3.500% 1,000 1,000 New York 880591DU3 6/7/2043 4.962% (3) 185 (1) 195 New York, Luxembourg 880591CF7 7/15/2045 6.235% 7/15/2020 140 140 New York 880591EB4 1/15/2048 4.875% 500 500 New York, Luxembourg 880591DZ2 4/1/2056 5.375% 1,000 1,000 New York 880591EJ7 9/15/2060 4.625% 1,000 1,000 New York 880591ES7 9/15/2065 4.250% 1,000 1,000 New York Subtotal 19,225 20,300 Unamortized discounts, premiums, issue costs, and other (131 ) (143 ) Total long-term outstanding power bonds, net 19,094 20,157 Long-term debt of VIEs, net 1,089 1,127 Long-term notes payable — 23 Total long-term debt, net $ 20,183 $ 21,307 Notes (1) Includes net exchange gain from currency transactions of $191 million and $ 147 million at September 30, 2019 and 2018 , respectively. (2) Includes one electronotes ® issue with partial maturities of principal for each required annual payment. (3) The coupon rate represents TVA's effective interest rate. (4) TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions. See Put and Call Options above. (5) The bonds are callable on or after the dates shown. Maturities Due in the Year Ending September 30 2020 2021 2022 2023 2024 Thereafter Total Long-term power bonds, long-term debt of VIEs, and notes payable including current maturities (1) $ 1,092 $ 1,901 $ 1,071 $ 69 $ 1,057 $ 16,415 $ 21,605 Short-term debt, net of discounts 922 — — — — — 922 Note (1) Long-term power bonds does not include non-cash items of foreign currency exchange gain of $ 191 million , unamortized debt issue costs of $50 million , and net discount on sale of Bonds of $ 81 million . Long-term debt of VIE does not include non-cash item of unamortized debt issue costs of $ 8 million . Credit Facility Agreements 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 2019 with a maturity date of September 30, 2020. 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 one year or less. There were no outstanding borrowings under the facility at September 30, 2019 . The availability of this credit facility may be impacted by how the U.S. government addresses the possibility of approaching its debt limit. TVA also has funding available under the four long-term revolving credit facilities totaling $2.7 billion : a $150 million credit facility that matures on December 11, 2021, a $500 million credit facility that matures on February 1, 2022, a $1.0 billion credit facility that matures on June 13, 2023, and a $1.0 billion credit facility that matures on September 28, 2023. 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, 2019 and 2018, there were $1.3 billion and $921 million , respectively, of letters of credit outstanding under the facilities, and there were no borrowings outstanding. See Note 15 — Risk Management Activities and Derivative Transactions — Other Derivative Instruments — Collateral . The following table provides additional information regarding TVA's funding available under the four long-term revolving credit facilities: Summary of Long-Term Credit Facilities At September 30, 2019 Maturity Date Facility Limit Letters of Credit Outstanding Cash Borrowings Availability December 2021 $ 150 $ 38 $ — $ 112 February 2022 500 500 — — June 2023 1,000 494 — 506 September 2023 1,000 310 — 690 Total $ 2,650 $ 1,342 $ — $ 1,308 Lease/Leasebacks TVA previously entered into leasing transactions to obtain third-party financing for 24 peaking combustion turbine units ("CTs") as well as certain qualified technological equipment and software ("QTE") . Due to TVA's continuing involvement with the combustion turbine facilities and the QTE during the leaseback term, TVA accounted for the lease proceeds as financing obligations. On September 30, 2019 and 2018 , the outstanding le aseback obligations related to the remaining CTs and QTE were $263 million and $301 million , respectively. In March 2019, TVA made final rent payments under lease/leaseback transactions involving eight CTs, and TVA had previously acquired the equity interests related to these transactions. These transactions were terminated in July 2019. Final rent payments are scheduled to be made under the remaining CT lease/leaseback transactions on various dates from May 2020 to January 2022. TVA has already acquired the equity interests related to transactions involving eight of these CTs and will have the option to acquire the equity interests related to transactions involving the remaining eight CTs for additional amounts. |
Accumulated Other Comprehensive
Accumulated Other Comprehensive Income (Loss) | 12 Months Ended |
Sep. 30, 2019 | |
Equity [Abstract] | |
Accumulated Other Comprehensive Income (Loss) | Accumulated Other Comprehensive Income (Loss) AOCI represents market valuation adjustments related to TVA's currency swaps. The currency swaps are cash flow hedges and are the only derivatives in TVA's portfolio that have been designated and qualify for hedge accounting treatment. TVA records exchange rate gains and losses on its foreign currency-denominated debt and any related accrued interest in net income and marks its currency swap assets and liabilities to market through other comprehensive income (loss) ("OCI") . TVA then reclassifies an amount out of AOCI into net income, offsetting the exchange gain/loss recorded on the debt. For the years ended September 30, 2019 and 2018 , TVA reclassified $45 million and $ 26 million of losses, respectively, related to its cash flow hedges from AOCI to Interest expense. See Note 15 — Risk Management Activities and Derivative Transactions . 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 AOCI or that would impact the statements of operations are recorded as regulatory assets or regulatory liabilities. See Note 8 — Regulatory Assets and Liabilities for a schedule of regulatory assets and liabilities. See Note 15 — Risk Management Activities and Derivative Transactions for a discussion of the recognition in AOCI of gains and losses associated with certain derivative contracts. See Note 16 — Fair Value Measurements for a discussion of the recognition of certain investment fund gains and losses as regulatory assets and liabilities. See Note 21 — Benefit Plans for a discussion of the regulatory accounting related to components of TVA's benefit plans. |
Risk Management Activities and
Risk Management Activities and Derivative Transactions | 12 Months Ended |
Sep. 30, 2019 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Risk Management Activities and Derivative Transactions | Risk Management Activities and Derivative Transactions TVA is exposed to various risks. These include 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. Other than certain derivative instruments in its trust investment funds, it is TVA's policy to enter into these derivative transactions solely for hedging purposes and not for speculative purposes. TVA has suspended its FTP and no longer uses financial instruments to hedge risks related to commodity prices; however, TVA plans to continue to manage fuel price volatility through other methods and to periodically reevaluate its suspended FTP program for future use of financial instruments. 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 Derivatives in Cash Flow Hedging Relationship Objective of Hedge Transaction Accounting for Derivative 2019 2018 Currency swaps To protect against changes in cash flows caused by changes in foreign currency exchange rates (exchange rate risk) Unrealized gains and losses are recorded in AOCI and reclassified to interest expense to the extent they are offset by gains and losses on the hedged transaction $ (114 ) $ 10 Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2) (1) Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income to Interest Expense For the years ended September 30 Derivatives in Cash Flow Hedging Relationship 2019 2018 Currency swaps $ (45 ) $ (26 ) Note (1) There were no ineffective portions or amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $30 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 exchange gain 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 Derivative Type Objective of Derivative Accounting for Derivative Instrument 2019 2018 Interest rate swaps To fix short-term debt variable rate to a fixed rate (interest rate risk) Mark-to-Market gains and losses are recorded as regulatory assets or liabilities $ (79 ) $ (89 ) Commodity derivatives To protect against fluctuations in market prices of purchased commodities (price risk) Mark-to-Market gains and losses are recorded as regulatory assets or liabilities — (8 ) Note (1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the years ended September 30, 2019 and 2018 . Fair Values of TVA Derivatives At September 30 2019 2018 Derivatives That Receive Hedge Accounting Treatment: Balance Balance Sheet Presentation Balance Balance Sheet Presentation Currency swaps £200 million Sterling $ (90 ) Accounts payable and accrued liabilities $(6); Other long-term liabilities $(84) $ (67 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(62) £250 million Sterling (61 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(56) (12 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(7) £150 million Sterling (57 ) Accounts payable and accrued liabilities $(4); Other long-term liabilities $(53) (15 ) Accounts payable and accrued liabilities $(3); Other long-term liabilities $(12) Derivatives That Do Not Receive Hedge Accounting Treatment: Balance Balance Sheet Presentation Balance Balance Sheet Presentation Interest rate swaps $1.0 billion notional $ (1,261 ) Accounts payable and accrued liabilities $(62); Other long-term liabilities $(1,199) $ (878 ) Accounts payable and $476 million notional (498 ) Accounts payable and accrued liabilities $(24); Other long-term liabilities $(474) (317 ) Accounts payable and $42 million notional (5 ) Accounts payable and accrued liabilities $(2); Other long-term liabilities $(3) (4 ) Accounts payable and Commodity contract derivatives (41 ) Other current assets $12; Other long-term liabilities $(16); Accounts payable and accrued liabilities $(37) 60 Other current assets $41; Other long-term assets $31; Other long-term liabilities $(8); Accounts payable and accrued liabilities $(4) Cash Flow Hedging Strategy for Currency Swaps To protect against exchange rate risk related to three 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, 2019 : Currency Swaps Outstanding At September 30, 2019 Effective Date of Currency Swap Contract Associated TVA Bond Issues Currency Exposure Expiration Date of Swap Overall Effective Cost to TVA 1999 £200 million 2021 5.81% 2001 £250 million 2032 6.59% 2003 £150 million 2043 4.96% 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 Accounts payable and accrued liabilities, 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 assets or liabilities 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 Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets, and realized gains and losses, if any, are included in TVA's Consolidated Statements of Operations. For the years ended September 30, 2019 and 2018 , the changes in fair market value of the interest rate swaps resulted in the deferral of unrealized losses of $ 565 million and unrealized gains of $ 310 million , respectively. Commodity Derivatives . TVA enters into certain derivative contracts for coal and natural gas that require physical delivery of the contracted quantity of the commodity. TVA marks to market all such contracts and defers the fair market values as regulatory assets or liabilities on a gross basis. At September 30, 2019 , TVA's coal and natural gas contract derivatives both had terms of up to three years. Commodity Contract Derivatives At September 30 2019 2018 Number of Contracts Notional Amount Fair Value (MtM) Number of Contracts Notional Amount Fair Value ( MtM ) Coal contract derivatives 8 9 million tons $ (4 ) 13 20 million tons $ 58 Natural gas contract derivatives 65 330 million mmBtu $ (37 ) 61 359 million mmBtu $ 2 Derivatives Under FTP. TVA has suspended its FTP and no longer uses financial instruments to he dge risks related to commodity prices. Prior to the suspension of the FTP, TVA deferred all FTP unrealized gains (losses) as regulatory liabilities (assets) and recorded only realized gains or losses to match the delivery period of the underlying commodity. TVA did not experience any unrealized gains and losses related to the FTP at September 30, 2019 or September 30, 2018 . TVA experienced the following realized losses related to the FTP during the periods set forth in the table below: Financial Trading Program Realized Gains (Losses) For the years ended September 30 Decrease (increase) in fuel expense 2019 2018 Natural gas $ — $ (6 ) Decrease (increase) in purchased power expense Natural gas $ — $ (2 ) Offsetting of Derivative Assets and Liabilities The amounts of TVA's derivative instruments as reported on the Consolidated Balance Sheets at September 30, 2019 and 2018, are shown in the table below. Derivative Assets and Liabilities At September 30, 2019 Gross Amounts of Recognized Assets/Liabilities Gross Amounts Offset in the Balance Sheet (1) Net Amounts of Assets/Liabilities Presented in the Balance Sheet (2) Assets Commodity derivatives not subject to master netting or similar arrangement $ 12 $ — $ 12 Liabilities Currency swaps (3) $ 208 $ — $ 208 Interest rate swaps (3) 1,764 — 1,764 Total derivatives subject to master netting or similar arrangement 1,972 — 1,972 Commodity derivatives not subject to master netting or similar arrangement 53 — 53 Total liabilities $ 2,025 $ — $ 2,025 At September 30, 2018 Gross Amounts of Recognized Assets/Liabilities Gross Amounts Offset in the Balance Sheet (1) Net Amounts of Assets/Liabilities Presented in the Balance Sheet (2) Assets Commodity derivatives not subject to master netting or similar arrangement $ 72 $ — $ 72 Liabilities Currency swaps (3) $ 94 $ — $ 94 Interest rate swaps (3) 1,199 — 1,199 Total derivatives subject to master netting or similar arrangement 1,293 — 1,293 Commodity derivatives not subject to master netting or similar arrangement 12 — 12 Total liabilities $ 1,305 $ — $ 1,305 Notes (1) Amounts primarily include counterparty netting of derivative contracts, margin account deposits for futures commission merchants transactions, and cash collateral received or paid in accordance with the accounting guidance for derivatives and hedging transactions. (2) There are no derivative contracts subject to a master netting arrangement or similar agreement that are not offset on the Consolidated Balance Sheets. (3) Letters of credit of approximately $1.3 billion and $ 921 million were posted as collateral at September 30, 2019 and 2018 , respectively, to partially secure the liability positions of one of the currency swaps and one of the interest rate swaps in accordance with the collateral requirements for these derivatives. Other Derivative Instruments Investment Fund Derivatives . Investment funds consist primarily of funds held in the NDT, ART, SERP, and DCP. See Note 16 — Fair Value Measurements — Investments 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, 2019 and 2018 , the NDT held investments in forward contracts to purchase debt securities. The fair values of these derivatives were in net asset positions totaling $22 million and $45 million at September 30, 2019 and 2018 , respectively. Collateral . TVA's interest rate swaps and currency swaps 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, 2019 , the aggregate fair value of all derivative instruments with credit-risk related contingent features that were in a liability position was $2.0 billion . TVA's collateral obligations at September 30, 2019 , under these arrangements, were approximately $1.3 billion , for which TVA had posted approximately $1.3 billion 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 contract as a result of this posted collateral. For all of its derivative instruments with credit-risk related contingent features: • If TVA remains a majority-owned U.S. government entity but Standard & Poor's Financial Services, LLC ("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, to mitigate credit risk. 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 $1.6 billion of receivables from power sales outstanding at both September 30, 2019 and 2018 , nearly all counterparties were rated investment grade. 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 and Note 3 — Accounts Receivable, Net . TVA had revenue from two LPCs that accounted for 17 percent of total operating revenue for the years ended both September 30, 2019 and September 30, 2018 . Suppliers . If one of TVA's fuel or purchased power suppliers fails to perform under the terms of its contract with TVA, TVA might lose the mone y 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. Nuclear fuel requirements, including uranium mining and milling, conversion services, enrichment services, and fabrication services, are met from various suppliers, depending on the type of service. TVA purchases the majority of its natural gas requirements from a variety of suppliers under short-term contracts. To help ensure a reliable supply of coal, TVA had coal contracts with multiple suppliers at September 30, 2019 . The contracted su pply of coal is sourced from multiple geographic regions of the United States and is to be delivered via various transportation methods (e.g., barge, rail, and truck). Emerging technologies, environmental regulations, and low natural gas prices have contributed to weak demand for coal. As a result, coal suppliers are facing increased financial pressure, which has led to relatively poor credit ratings and bankruptcies. Continued difficulties by coal suppliers could result in consolidations, additional bankruptcies, restructurings, contract renegotiations, or other scenarios. Under these scenarios and TVA's potential available responses, TVA does not anticipate a significant financial impact in obtaining continued fuel supply for its coal-fired generation. 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 can be obtained, although at prices that may be unfavorable when compared to the prices under the current supply agreements. TVA has a power purchase agreement that expires on March 31, 2032, with a supplier of electricity for 440 megawatts ("MW") of summer net capability from a lignite-fired generating plant. TVA has determined that the supplier has the equivalent of a non-investment grade credit rating; therefore, the supplier has provided credit assurance to TVA under the terms of the agreement. Derivative Counterparties . TVA has entered into physical and financial contracts that qualify as derivatives for hedging purposes, and TVA's NDT, ART, and qualified defined benefit 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 substantial costs in connection with entering into a replacement transaction. If a counterparty to the derivative contracts into which the NDT, ART, and qualified 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, 2019 , all of TVA's currency swaps and interest rate swaps as well as all of the derivatives in the NDT and ART were with banking counterparties whose Moody's credit ratings were A3 or higher. TVA classifies qualified forward coal and natural gas contracts as derivatives. See Derivatives Not Receiving Hedge Accounting Treatment above. At September 30, 2019 , the coal contracts were with counterparties whose Moody's credit rating, or TVA's internal analysis when such information was unavailable, ranged from D to Ba3 . At September 30, 2019 , the natural gas contracts were with counterparties whose ratings ranged from B1 to A2 . See Suppliers above for discussion of challenges facing the coal industry. |
Fair Value Measurements
Fair Value Measurements | 12 Months Ended |
Sep. 30, 2019 | |
Fair Value Disclosures [Abstract] | |
Fair Value Measurements | Fair Value Measurements Fair value is determined based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the asset or liability's principal market, or in the absence of a principal market, the most advantageous market for the asset or liability in an orderly transaction between market participants. TVA uses market or observable inputs as the preferred source of values, followed by assumptions based on hypothetical transactions in the absence of market inputs. Valuation Techniques The measurement of fair value results in classification into a hierarchy by the inputs used to determine the fair value as follows: Level 1 — Unadjusted quoted prices in active markets accessible by the reporting entity for identical assets or liabilities. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing. Level 2 — Pricing inputs other than quoted market prices included in Level 1 that are based on observable market data and that are directly or indirectly observable for substantially the full term of the asset or liability. These include quoted market prices for similar assets or liabilities, quoted market prices for identical or similar assets in markets that are not active, adjusted quoted market prices, inputs from observable data such as interest rate and yield curves, volatilities and default rates observable at commonly quoted intervals, and inputs derived from observable market data by correlation or other means. Level 3 — Pricing inputs that are unobservable, or less observable, from objective sources. Unobservable inputs are only to be used to the extent observable inputs are not available. These inputs maintain the concept of an exit price from the perspective of a market participant and should reflect assumptions of other market participants. An entity should consider all market participant assumptions that are available without unreasonable cost and effort. These are given the lowest priority and are generally used in internally developed methodologies to generate management's best estimate of the fair value when no observable market data is available. A financial instrument's level within the fair value hierarchy (where Level 1 is the highest and Level 3 is the lowest) is based on the lowest level of input significant to the fair value measurement. The following sections describe the valuation methodologies TVA uses to measure different financial instruments at fair value. Except for gains and losses on SERP and DCP assets, all changes in fair value of these assets and liabilities have been recorded as changes in regulatory assets, regulatory liabilities, or AOCI on TVA's Consolidated Balance Sheets and Consolidated Statements of Comprehensive Income (Loss). Except for gains and losses on SERP and DCP assets, there has been no impact to the Consolidated Statements of Operations or the Consolidated Statements of Cash Flows related to these fair value measurements. Investment Funds At September 30, 2019 , Investment funds were composed of $3.0 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, and DCP. 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 $2.1 billion and $765 million , respectively, at September 30, 2019 . 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 until employment with TVA ends. The NDT, ART, SERP, and DCP 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, and DCP are composed of multiple types of investments and are managed by external institutional investment managers. Most U.S. and international equities, U.S. Treasury inflation-protected securities, real estate investment trust securities, and cash securities and certain derivative instruments are measured based on quoted exchange prices in active markets and are classified as Level 1 valuations. Fixed-income investments, high-yield fixed-income investments, currencies, and most derivative instruments are non-exchange traded and are classified as Level 2 valuations. These measurements are based on market and income approaches with observable market inputs. Private equity limited partnerships, private real asset investments, and private credit investments may include holdings of investments in private real estate, venture capital, buyout, mezzanine or subordinated debt, restructuring or distressed debt, and special situations through funds managed by third-party investment managers. These investments generally involve a three -to- four -year period where the investor contributes capital, followed by a period of distribution, typically over several years. The investment period is generally, at a minimum, 10 years or longer. The NDT had unfunded commitments related to private equity limited partnerships of $191 million , unfunded commitments related to private real assets of $33 million , and unfunded commitments related to private credit of $22 million at September 30, 2019 . The ART had unfunded commitments related to private equity limited partnerships of $96 million , unfunded commitments related to private real assets of $19 million , and unfunded commitments related to private credit of $11 million at September 30, 2019 . 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 net asset value in the fair value hierarchy. Commingled funds represent investment funds comprising multiple individual financial instruments. The commingled funds held by the NDT, ART, SERP, and DCP 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 net asset value 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 . TVA recorded unrealized gains and losses related to its equity and trading debt securities held during each period as follows: Unrealized Investment Gains (Losses) At or for the years ended September 30 Fund Financial Statement Presentation 2019 2018 NDT Regulatory asset $ (112 ) $ 18 ART Regulatory asset (70 ) 15 SERP Other income (expense) — 1 DCP Other income (expense) (2 ) 1 Currency and Interest Rate Derivatives See Note 15 — 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 Most of these contracts are valued based on market approaches which utilize short- and mid-term market-quoted prices from an external industry brokerage service. A small number of these contracts are valued based on a pricing model using long-term price estimates from TVA's coal price forecast. To value the volume option component of applicable coal contracts, TVA uses a Black-Scholes pricing model which includes inputs from the forecast, contract-specific terms, and other market inputs. These contracts are classified as Level 3 valuations. 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 2018) 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 $ 1 million decrease in the fair value of liabilities at September 30, 2019 . 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, 2019 and 2018 . 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, 2019 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 $ 464 $ — $ — $ 464 Government debt securities 279 65 — 344 Corporate debt securities — 417 — 417 Mortgage and asset-backed securities — 32 — 32 Institutional mutual funds 250 — — 250 Forward debt securities contracts — 22 — 22 Private equity funds measured at net asset value (1) — — — 140 Private real asset funds measured at net asset value (1) — — — 135 Private credit measured at net asset value (1) — — — 33 Commingled funds measured at net asset value (1) — — — 1,131 Total investments 993 536 — 2,968 Commodity contract derivatives — 7 5 12 Total $ 993 $ 543 $ 5 $ 2,980 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 (2) $ — $ 208 $ — $ 208 Interest rate swaps — 1,764 — 1,764 Commodity contract derivatives — 44 9 53 Total $ — $ 2,016 $ 9 $ 2,025 Notes (1) Certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been categorized in the fair value hierarchy. 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. (2) 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 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities. Fair Value Measurements At September 30, 2018 Quoted Prices in Active Significant Other Significant Total Assets Investments Equity securities $ 220 $ — $ — $ 220 Government debt securities 199 37 — 236 Corporate debt securities — 499 — 499 Mortgage and asset-backed securities — 50 — 50 Institutional mutual funds 126 — — 126 Forward debt securities contracts — 45 — 45 Private equity funds measured at net asset value (1) — — — 132 Private real asset funds measured at net asset value (1) — — — 124 Commingled funds measured at net asset value (1) — — — 1,430 Total investments 545 631 — 2,862 Commodity contract derivatives — 13 59 72 Total $ 545 $ 644 $ 59 $ 2,934 Quoted Prices in Active Markets for Identical Liabilities Significant Other Significant Total Liabilities Currency swaps (2) $ — $ 94 $ — $ 94 Interest rate swaps — 1,199 — 1,199 Commodity contract derivatives — 11 1 12 Total $ — $ 1,304 $ 1 $ 1,305 Notes (1) Certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been categorized in the fair value hierarchy. 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. (2) 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 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities . TVA uses internal valuation specialists for the calculation of its commodity contract derivatives fair value measurements classified as Level 3. Analytical testing is performed on the change in fair value measurements each period to ensure the valuation is reasonable based on changes in general market assumptions. Significant changes to the estimated data used for unobservable inputs, in isolation or combination, may result in significant variations to the fair value measurement reported. The following table presents a reconciliation of all commodity contract derivatives measured at fair value on a recurring basis using significant unobservable inputs (Level 3): Fair Value Measurements Using Significant Unobservable Inputs Commodity Contract Derivatives Balance at October 1, 2017 $ (67 ) Change in net unrealized gains (losses) deferred as regulatory assets and liabilities 125 Balance at September 30, 2018 58 Change in net unrealized gains (losses) deferred as regulatory assets and liabilities (62 ) Balance at September 30, 2019 $ (4 ) The following table presents quantitative information related to the significant unobservable inputs used in the measurement of fair value of TVA's assets and liabilities classified as Level 3 in the fair value hierarchy: Quantitative Information about Level 3 Fair Value Measurements Fair Value at September 30, 2019 Valuation Technique(s) Unobservable Inputs Range Assets Commodity contract derivatives $ 5 Pricing model Coal supply and demand 0.4 - 0.8 billion tons/year Long-term market prices $12.10 - $94.51/ton Liabilities Commodity contract derivatives $ 9 Pricing model Coal supply and demand 0.4 - 0.8 billion tons/year Long-term market prices $12.10 - $94.51/ton Quantitative Information about Level 3 Fair Value Measurements Fair Value at September 30, 2018 Valuation Technique(s) Unobservable Inputs Range Assets Commodity contract derivatives $ 59 Pricing model Coal supply and demand 0.7 - 0.8 billion tons/year Long-term market prices $12.25 - $112.24/ton Liabilities Commodity contract derivatives $ 1 Pricing model Coal supply and demand 0.7 - 0.8 billion tons/year Long-term market prices $12.25 - $112.24/ton 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 instrument. The fair value of the financial instruments held at September 30, 2019 and 2018 , 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, 2019 and 2018 , were as follows: Estimated Values of Financial Instruments Not Recorded at Fair Value At September 30, 2019 At September 30, 2018 Valuation Classification Carrying Fair Value Carrying Fair Value EnergyRight ® receivables (including current portion) Level 2 $ 101 $ 100 $ 112 $ 112 Loans and other long-term receivables, net (including current portion) Level 2 $ 131 $ 120 $ 138 $ 123 EnergyRight ® financing obligation (including current portion) Level 2 $ 113 $ 126 $ 127 $ 143 Unfunded loan commitments Level 2 $ — $ 10 $ — $ 3 Membership interests of VIEs subject to mandatory redemption (including current portion) Level 2 $ 28 $ 37 $ 30 $ 37 Long-term outstanding power bonds (including current maturities), net Level 2 $ 20,124 $ 26,059 $ 21,189 $ 23,896 Long-term debt of VIEs (including current maturities), net Level 2 $ 1,128 $ 1,371 $ 1,165 $ 1,256 Long-term notes payable (including current maturities) Level 2 $ 23 $ 23 $ 69 $ 68 The carrying value of Cash and cash equivalents, Restricted cash and cash equivalents, 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. |
Proprietary Capital
Proprietary Capital | 12 Months Ended |
Sep. 30, 2019 | |
Stockholders' Equity Note [Abstract] | |
Proprietary Capital | Proprietary Capital Appropriation Investment 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. The table below summarizes TVA's activities related to appropriated funds and retained earnings. Summary of Proprietary Capital Activity At or for the years ended September 30 2019 2018 Power Program Nonpower Programs Power Program Nonpower Programs Appropriation Investment $ 258 $ 4,351 $ 258 $ 4,351 Retained Earnings Balance at beginning of year 9,404 (3,787 ) 8,282 (3,779 ) Net income (loss) for year 1,425 (8 ) 1,127 (8 ) Return on power program appropriation investment (6 ) — (5 ) — Balance at end of year 10,823 (3,795 ) 9,404 (3,787 ) Net proprietary capital at September 30 $ 11,081 $ 556 $ 9,662 $ 564 Payments to the U.S. Treasury TVA paid the U.S. Treasury $ 6 million , $ 5 million , and $ 5 million in 2019 , 2018 , and 2017 , 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 2.37 percent , 2.09 percent , and 2.00 percent for 2019 , 2018 , and 2017 , respectively. Accumulated Other Comprehensive Income (Loss) The items included in AOCI consist of market valuation adjustments for certain derivative instruments. See Note 15 — Risk Management Activities and Derivative Transactions . TVA records exchange rate gains and losses on debt and related accrued interest in net income and marks its currency swap assets and liabilities to market through OCI. TVA recognized unrealized gains (losses) of $ (114) million and $ 10 million in 2019 and 2018 , respectively, into AOCI on the mark-to-market of currency swaps. TVA then reclassifies an amount out of AOCI into net income, offsetting the gain/loss from recording the exchange gain/loss on the debt and related accrued interest. The amounts reclassified from OCI into net income resulted in increases (decreases) to net income of $ (45) million , $ (26) million , and $ 26 million in 2019 , 2018 , and 2017 , respectively. These reclassifications, coupled with the recording of the exchange gain/loss on the debt and related accrued interest, did not have an impact on net income in 2019 , 2018 , and 2017 . Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $30 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 exchange gain on the debt and related accrued interest. |
Other Income (Expense), Net
Other Income (Expense), Net | 12 Months Ended |
Sep. 30, 2019 | |
Other Income and Expenses [Abstract] | |
Other Income (Expense), Net | Other Income (Expense), Net Income and expenses not related to TVA's operating activities are summarized in the following table: Other Income (Expense), Net For the years ended September 30 2019 2018 2017 Bellefonte deposit $ 21 $ — $ — Interest income 25 23 23 External services 13 14 14 Gains (losses) on investments 3 6 9 Miscellaneous — 7 10 Total other income (expense), net $ 62 $ 50 $ 56 During 2019 , Other income (expense), net increased $12 million primarily driven by other income related to a $21 million deposit liability received by TVA as a down payment on the sale of Bellefonte. The purchaser, Nuclear Development, LLC, failed to fulfill the requirements of the sales contract with respect to obtaining NRC approval of the transfer of required nuclear licenses and payment of the remainder of the selling price before the November 30, 2018 closing date. Partially offsetting this increase was a decrease of $5 million resulting from gains on the disposition of prior year property and $2 million of unrealized losses on the SERP and DCP investments. |
Supplemental Cash Flow Informat
Supplemental Cash Flow Information | 12 Months Ended |
Sep. 30, 2019 | |
Supplemental Cash Flow Information [Abstract] | |
Supplemental Cash Flow Information | Supplemental Cash Flow Information Interest paid was $ 1.2 billion for both 2019 and 2018 and $1.3 billion for 2017 . These amounts differ from interest expense in certain years due to the timing of payments and interest capitalized for major capital expenditures. There was no interest capitalized in 2019 , 2018 , or 2017 . Construction in progress and Nuclear fuel expenditures included in Accounts payable and accrued liabilities at September 30, 2019 , 2018 , and 2017 were $324 million , $372 million , and $425 million , respectively, and are excluded from the Statements of Consolidated Cash Flows for the years ended September 30, 2019 , 2018 and 2017 as non-cash investing activities. Excluded from the Statements of Consolidated Cash Flows for the years ended September 30, 2019 and 2017 as non-cash financing activities were capital lease obligations incurred related to $10 million of leased equipment in 2019 and $10 million of purchase power assets in 2017. There were no capital leases incurred during 2018 . Also excluded from the Statement of Consolidated Cash Flows for the year ended September 30, 2017 was $74 million of notes payable related to TVA's acquisition of equity interests in certain SPEs. See Note 9 — Asset Acquisitions . 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. |
Benefit Plans
Benefit Plans | 12 Months Ended |
Sep. 30, 2019 | |
Retirement Benefits [Abstract] | |
Benefit Plans | Benefit Plans TVA sponsors a qualified defined benefit plan ("pension plan") that covers most of its full-time employees hired prior to July 1, 2014, a qualified defined contribution plan ("401(k) plan") that covers most of its full-time employees, two unfunded post-retirement health care plans that provide for non-vested contributions toward the cost of eligible retirees' medical coverage, other postemployment benefits such as workers' compensation, and the SERP. The pension plan and the 401(k) plan are administered by a separate legal entity, the TVA Retirement System ("TVARS") , which is governed by its own board of directors (the "TVARS Board"). Overview of Plans and Benefits Retirement Plans. The participants in the pension plan receive either a traditional final average pay pension or a cash balance pension. The traditional pension benefit is based on the participant's creditable service, average monthly salary for their highest three consecutive years of eligible compensation, and a pension factor based on the participant's age and years of service, less a Social Security offset. The cash balance pension benefit is based on pay and interest credits accumulated in the participant's account and the participant's age. Participants in the pension plan are also eligible to receive 401(k) plan matching contributions, may be eligible to receive 401(k) plan non-elective contributions, and may be eligible to make after-tax contributions of up to $ 10,000 per year to the pension plan, which at the election of the participant are invested in either the fixed fund, which receives a fixed interest rate set forth in the plan, or the variable fund, which receives a rate of return based on an S&P 500 index fund. Participants in the pension plan may also become eligible for a supplemental pension benefit based on age and years of service at retirement, which is provided to help offset the cost of retiree medical insurance. Employees first hired on or after July 1, 2014, are participants in the 401(k) plan only and receive both non-elective and matching contributions to their accounts in the 401(k) plan. On May 23, 2018, the TVARS Board approved amendments to the pension plan and 401(k) plan. These amendments allowed employees who are continuing to accrue cash balance benefits in the pension plan to voluntarily elect to switch future participation to the 401(k) plan only, and employees with cash balance accounts in the pension plan who have a 401(k) only benefit the additional option to waive their rights to benefits under the pension plan and transfer their cash balance accounts (and fixed and variable accounts, if any) to the 401(k) plan. TVARS presented these amendments to TVA for its review and consideration, and the amendments became effective July 8, 2018. Under the plan amendments, the voluntary election options were offered to eligible TVA employees during a two-month window from July 1, 2018, to August 31, 2018, with changes and transfers becoming effective on October 1, 2018. As a result, there were $23 million of one-time transfers to the 401(k) plan based upon employee elections. These amendments did not trigger curtailment or settlement accounting. 401(k) Plan . Under the 401(k) plan, the non-elective and matching contributions TVA makes to participant accounts are based on the participant's employment hire date and years of service. Non-elective employer contributions for eligible participants range from three percent to six percent and matching employer contributions range from 1.5 percent to six percent. TVA recognized $ 84 million in 401(k) plan contribution costs in 2019 . TVA recognized $ 80 million in 401(k) plan contribution costs in both 2018 and 2017 . The 2020 plan contribution costs are estimated to be approximately $88 million . Supplemental Executive Retirement Plan. TVA has established a SERP for certain executives in critical positions to provide supplemental pension benefits tied to compensation that exceeds limits imposed by IRS rules applicable to the qualified defined benefit pension plan. Other Post-Retirement Benefits. TVA sponsors two unfunded post-retirement benefit plans that provide for non-vested contributions toward the cost of certain eligible retirees' medical coverage. The first plan covers only certain retirees and surviving dependents who do not qualify for TVARS benefits, including the supplemental pension benefit. The second plan is designed to place a limit on the out-of-pocket amount certain eligible retirees pay for medical coverage and provides a credit based on years of TVA service and monthly base pension amount, reduced by any TVARS supplemental pension benefits or any TVA contribution from the first plan, described above. Effective January 2017, all Medicare-eligible retirees and spouses were provided Medicare coverage through a private exchange. Transition to the exchange does not affect any TVARS supplemental benefits for eligible retirees, and the credit will continue to be calculated in the same manner as before. Other Post-Employment Benefits. TVA employees injured in work-related incidents are covered by the workers' compensation program for federal employees administered through the Department of Labor by the Office of Workers' Compensation Programs in accordance with the provisions of the Federal Employees' Compensation Act ("FECA") . FECA provides compensation and medical benefits to federal employees for permanent and temporary disability due to employment-related injury or disease. 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 recent plan design changes, future contributions are expected to exceed the expense calculated under U.S. GAAP. Accordingly, TVA will discontinue this regulatory accounting practice once all such deferred costs have been recovered, at which time it will recognize pension costs in accordance with U.S. GAAP. 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 remaining service period of participating employees expected to receive benefits. The current projected amortization periods of unrecognized net gain or loss is approximately 10 years for the pension plan and 12 years for the post-retirement plan. 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 have prior service costs/(credits) related to plan changes made in 2009, 2010, 2016, 2018, and 2019 with remaining amortization periods ranging from one to 10 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. Obligations and Funded Status The changes in plan obligations, assets, and funded status for the years ended September 30, 2019 and 2018 , were as follows: Obligations and Funded Status For the years ended September 30 798,000,000 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Change in benefit obligation Benefit obligation at beginning of year $ 11,725 $ 12,601 $ 428 $ 494 Service cost 44 53 11 14 Interest cost 499 473 18 19 Plan participants' contributions 7 7 — — Collections (1) — — 22 25 Actuarial (gain) loss 1,756 (658 ) 78 (46 ) Plan change 7 — — (17 ) Net transfers (to) from variable fund/401(k) plan (2) 1 (26 ) — — Expenses paid (6 ) (6 ) — — Benefits paid (721 ) (719 ) (58 ) (61 ) Benefit obligation at end of year 13,312 11,725 499 428 Change in plan assets Fair value of net plan assets at beginning of year 8,003 7,989 — — Actual return on plan assets 389 454 — — Plan participants' contributions 7 7 — — Collections (1) — — 22 25 Net transfers (to) from variable fund/401(k) plan (2) 1 (26 ) — — Employer contributions 307 304 36 36 Expenses paid (6 ) (6 ) — — Benefits paid (721 ) (719 ) (58 ) (61 ) Fair value of net plan assets at end of year 7,980 8,003 — — Funded status $ (5,332 ) $ (3,722 ) $ (499 ) $ (428 ) Notes (1) Collections include retiree contributions as well as provider discounts and rebates. (2) Includes one-time transfers to the 401(k) of $23 million related to the 2018 plan amendment. The pension actuarial loss for 2019 primarily reflects the impact of the decrease in the discount rate from 4.35 percent to 3.20 percent , which increased the liability by $1.6 billion . In addition, TVA recognized actuarial losses of $88 million resulting from the difference between the expected and actual return on plan assets and $59 million of experience losses. These actuarial losses were partially offset by a $14 million gain due to mortality assumption changes. The 2019 pension plan change of $7 million was a result of two new participants entering the SERP plan during 2019. The pension actuarial gain for 2018 primarily reflects the impact of the increase in the discount rate from 3.85 percent to 4.35 percent , which decreased the liability by $676 million . Based on the results obtained from the most recent experience study performed in 2018, TVA had gains of $138 million due to mortality assumption changes offset by losses of $46 million due to the revision of other demographic and experience based assumptions. In addition, TVA recognized losses related to the change in the assumptions on lump sum elections and annuity benefits as a result of the 2016 plan amendments, which increased the liability by $110 million . The other post-retirement actuarial loss for 2019 was primarily due to the decrease in the discount rate from 4.40 percent to 3.30 percent , which increased the liability by $71 million . TVA recognized losses of $24 million primarily due to the updated per capita claim costs assumption and an additional loss of $7 million related to actual experience different from assumed. These losses were partially offset by a net gain of $24 million due to the change in health care trend rate assumptions. The other post-retirement benefit actuarial gain for 2018 was primarily due to an increase in the discount rate from 3.95 percent to 4.40 percent , which decreased the liability by $28 million . Based on the results obtained from the recent experience study performed during 2018, TVA recognized gains of $6 million due to mortality assumption changes and $23 million of additional gains in other experience related assumptions. These gains were partially offset by losses of $8 million related to per capita claim costs and retiree contributions assumptions and $3 million in actuarial losses related to actual experience different from assumed. For CY 2019, TVA made plan changes to the other post-retirement benefit plan resulting in a decrease in the liability of $17 million for 2018. This decrease is primarily related to the use of a new national preferred formulary and utilization manager program. 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, 2019 and 2018 , 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 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Regulatory assets (liabilities) $ 4,731 $ 3,119 $ 25 $ (73 ) Accounts payable and accrued liabilities (5 ) (6 ) (28 ) (28 ) Pension and post-retirement benefit obligations (1) (5,327 ) (3,716 ) (471 ) (400 ) Note (1) The table above excludes $383 million and $360 million of post-employment benefit costs that are recorded in Post-retirement and post-employment benefit obligations on the Consolidated Balance Sheets at September 30, 2019 and 2018 , respectively. Unrecognized amounts included in regulatory assets or liabilities yet to be recognized as components of accrued benefit cost at September 30, 2019 and 2018 , consisted of the following: Post-Retirement Benefit Costs Deferred as Regulatory Assets (Liabilities) At September 30 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Unrecognized prior service credit $ (714 ) $ (819 ) $ (135 ) $ (159 ) Unrecognized net loss 5,350 3,842 160 86 Amount capitalized due to actions of regulator 95 96 — — Total regulatory assets (liabilities) $ 4,731 $ 3,119 $ 25 $ (73 ) The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for the pension plan at September 30, 2019 and 2018 , were as follows: Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets At September 30 2019 2018 Projected benefit obligation $ 13,312 $ 11,725 Accumulated benefit obligation 13,246 11,659 Fair value of net plan assets 7,980 8,003 The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the years ended September 30, 2019 , 2018 , and 2017 were as follows: Components of Net Periodic Benefit Cost For the years ended September 30 Pension Benefits Other Post-Retirement Benefits 2019 2018 2017 2019 2018 2017 Service cost $ 44 $ 53 $ 60 $ 11 $ 14 $ 18 Interest cost 499 473 464 18 19 21 Expected return on plan assets (477 ) (478 ) (457 ) — — — Amortization of prior service credit (99 ) (99 ) (99 ) (24 ) (22 ) (22 ) Recognized net actuarial loss 336 409 472 4 8 14 Total net periodic benefit cost as actuarially determined 303 358 440 9 19 31 Amount expensed (capitalized) due to actions of regulator 1 (54 ) 365 — — — Net periodic benefit cost $ 304 $ 304 $ 805 $ 9 $ 19 $ 31 The amounts in the regulatory asset that are expected to be recognized as components of net periodic benefit cost during the next fiscal year are as follows: Expected Amortization of Regulatory Assets in 2020 At September 30, 2019 Pension Benefits Other Post-Retirement Benefits Total Prior service credit $ (97 ) $ (24 ) $ (121 ) Net actuarial loss 435 9 444 The amount in the components of net periodic benefit cost expected to be deferred due to actions of the regulator in the next fiscal year is $ 13 million . Plan Assumptions TVA's reported costs of providing the plan benefits are impacted by numerous factors including the provisions of the plans, changing employee demographics, and various assumptions, the most significant of which are noted below. Actuarial Assumptions Utilized to Determine Benefit Obligations at September 30 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Discount rate 3.20 % 4.35 % 3.30 % 4.40 % Rate of compensation increase 3.50 % 3.60 % N/A N/A Cost of living adjustment (COLA) (1) 2.00 % 2.00 % 2.00 % 2.00 % Pre-Medicare eligible Initial health care cost trend rate N/A N/A 6.75 % 6.25 % Ultimate health care cost trend rate N/A N/A 5.00 % 5.00 % Year ultimate trend rate is reached N/A N/A 2027 2024 Post-Medicare eligible Initial health care cost trend rate N/A N/A — % — % Ultimate health care cost trend rate N/A N/A 4.00 % 4.00 % Year ultimate trend rate is reached N/A N/A 2023 2021 Note (1) The COLA rate is the ultimate long-term rate. Actuarial Assumptions Utilized to Determine Net Periodic Benefit Cost for the Years Ended September 30 (1) Pension Benefits Other Post-Retirement Benefits 2019 2018 2017 2019 2018 2017 Discount rate 4.35 % 3.85 % 3.65 % 4.40 % 3.95 % 3.70 % Expected return on plan assets 6.75 % 6.75 % 7.00 % N/A N/A N/A Cost of living adjustment (COLA) (2) 2.00 % 2.00 % 2.00 % 2.00 % 2.00 % 2.00 % Rate of compensation increase 3.50 % 5.34 % 5.43 % N/A N/A N/A Pre-Medicare eligible Initial health care cost trend rate N/A N/A N/A 6.25 % 6.50 % 6.50 % Ultimate health care cost trend rate N/A N/A N/A 5.00 % 5.00 % 5.00 % Year ultimate trend rate is reached N/A N/A N/A 2024 2024 2019 Post-Medicare eligible Initial health care cost trend rate N/A N/A N/A — % — % — % Ultimate health care cost trend rate N/A N/A N/A 4.00 % 4.00 % 4.00 % Year ultimate trend rate is reached N/A N/A N/A 2021 2021 2021 Notes (1) The actuarial assumptions used to determine the benefit obligations at September 30 of each year are subsequently used to determine net periodic benefit cost for the following year except the rate of compensation increase assumption. (2) The COLA assumption is the ultimate rate. The actual calendar year rate is used in determining the expense, and for years thereafter the ultimate rate is used. Discount Rate. In selecting the assumed discount rate, TVA reviews market yields on high-quality corporate debt and long-term obligations of the U.S. Treasury and endeavors to match, through the use of a hypothetical bond portfolio, instrument maturities with the maturities of its pension obligations in accordance with the prevailing accounting standards. The selected bond portfolio is derived from a universe of high quality corporate bonds of Aa-rated quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan's projected benefit payments discounted at this rate with the market value of the bonds selected. Rate of Return . The qualified defined benefit pension plan is the only plan that is funded with qualified plan assets. In determining the expected long-term rate of return on pension plan assets, TVA uses a process that incorporates actual historical asset class returns and an assessment of expected future performance and takes into consideration external actuarial advice, the current outlook on capital markets, the asset allocation policy, and the anticipated impact of active management. Asset allocations are periodically updated using the pension plan asset/liability studies and are part of the determination of the estimates of long-term rates of return. The TVARS asset allocation policy diversifies plan assets across multiple asset classes so as to minimize the risk of large losses. The asset allocation policy is designed to be dynamic in nature and responsive to changes in the funded status of TVARS. Changes in the expected return rates are based on annual studies performed by third party professional investment consultants. Taking into account changes in the plan's asset target allocation mix, capital market outlooks, and the most recent studies, TVA management adopted a 6.75 percent expected long-term rate of return on plan assets in 2017 to calculate the 2018 net periodic pension cost. There were no changes to the assumption in 2019 or 2018. The 6.75 percent expected long-term return on plan assets will be used to calculate the 2020 net periodic pension cost. Compensation Increases . Assumptions related to compensation increases are based on the results obtained from an actual company experience study performed during the most recent five years for plan participants. TVA obtained an updated study in 2018 and determined that future compensation would likely increase at rates between 2.50 percent and 14.00 percent per year, depending upon the employee's age. The average assumed compensation increase used to determine benefit obligations is based upon the current active participants. Mortality. The mortality assumption is comprised of a base table that represents the current future life expectancy adjusted by an improvement scale to project future improvements in life expectancy. TVA's mortality assumptions are based upon actuarial projections in combination with studies of the actual mortality experience of TVA's pension and post-retirement benefit plan participants while taking into consideration the published Society of Actuaries ("SOA") mortality table and projection scale at September 30. Based upon the recent 2018 experience study, TVA adjusted its version of the SOA RP-2014 mortality table to reflect increases in female mortality. In 2019, TVA adopted a modified version of the SOA MP-2018 improvement scale published by the SOA. The following mortality assumptions were used to determine the benefit obligations for the pension and other post-retirement benefit plans at September 30, 2019 , 2018 , and 2017 . Assumptions used to determine year-end benefit obligations are the assumptions used to determine the subsequent year's net periodic benefit costs. Mortality Assumptions At September 30 2019 2018 2017 Mortality table RP-2014 table (adjusted) RP-2014 table (adjusted) RP-2014 table (adjusted) Improvement scale MP-2018 (modified) MP-2017 (modified) RP-2016 (modified) Health Care Cost Trends. TVA reviews actual recent cost trends and projected future trends in establishing health care cost trend rates. In 2019, TVA changed both the pre-Medicare and post-Medicare health care cost trend rate assumptions adopted in 2017. The pre-Medicare initial health care trend rate was reset to 6.75 percent, the ultimate trend rate remained constant at 5.00 percent, and the year to reach the ultimate rate was extended to 2027 from 2023. The post-Medicare initial health care trend rate and ultimate health care cost trend rate remained constant at zero percent and 4.00 percent, respectively, whereas the year to reach the ultimate rate was extended to 2023 from 2021 attributable to lower than expected premium increases on the private exchange. Cost of Living Adjustment. COLAs are an increase in the benefits for eligible retirees to help maintain the purchasing power of benefits as consumer prices increase. Eligible retirees receive a COLA on pension and supplemental benefits equal to the percentage change in the Consumer Price Index for All Urban Consumers ("CPI-U") in January following any year in which the 12-month average CPI-U exceeded by as much as one percent the 12-month average of the CPI-U for the preceding year in which a COLA was given. Increases in the COLA will be the percent increase in CPI-U over the preceding year less 0.25 percent, with a 6.00 percent cap for any one year. TVA's COLA assumption is derived from long-term expectations of the expected future rate of inflation, based upon capital market assumptions, economic forecasts, and the Federal Reserve policy. The actual calendar year COLA and the long- term COLA assumption are used to determine the benefit obligation at September 30 and the net periodic benefit costs for the following fiscal year. The actual calendar year COLAs for 2019, 2018, and 2017 were 2.21 percent , 1.84 percent, and 0.99 percent, respectively. Sensitivity of Costs to Changes in Assumptions. The following chart reflects the sensitivity of pension cost to changes in certain actuarial assumptions: Sensitivity to Certain Changes in Pension Assumptions At September 30, 2019 Actuarial Assumption Change in Assumption Impact on 2019 Pension Cost Impact on 2019 Projected Benefit Obligation Discount rate (0.25 )% $ 16 $ 399 Rate of return on plan assets (0.25 )% 14 N/A Cost of living adjustments 0.25 % 27 261 Each fluctuation above assumes that the other components of the calculation are held constant and excludes any impact for unamortized actuarial gains or losses. The following chart reflects the sensitivity of post-retirement benefit cost to changes in the health care trend rate: Sensitivity to Changes in Assumed Health Care Cost Trend Rates At September 30, 2019 1% Increase 1% Decrease Effect on total of service and interest cost components for the year $ 4 $ (4 ) Effect on end-of-year accumulated post-retirement benefit obligation 71 (68 ) Each fluctuation above assumes that the other components of the calculation are held constant and excludes any impact for unamortized actuarial gains or losses. Plan Investments The TVARS asset allocation policy for qualified pension plan assets has targets of 43 percent equity including global public and private equity investments, 32 percent fixed income securities, and 25 percent real assets including public and private real assets. TVARS has a long-term investment plan that contains a dynamic de-risking strategy which will allocate investments to assets that better match the liability, such as long duration fixed income securities, over time as improved funding status targets are met. Pursuant to the TVARS Rules and Regulations, any proposed changes in asset allocation that would change TVARS's assumed rate of investment return are subject to TVA's review and veto. As set forth above, the qualified pension plan assets are invested across global public equity, private equity, safety oriented fixed income, opportunistic fixed income, public real assets, and private real assets. The TVARS asset allocation policy includes permissible deviations from target allocations, and action can be taken, as appropriate, to rebalance the plan's assets consistent with the asset allocation policy. At September 30, 2019 and 2018 , the asset holdings of TVARS included the following: Asset Holdings of TVARS At September 30 Plan Assets at September 30 Asset Category Target Allocation 2019 2018 Global public equity 35 % 37 % 44 % Private equity 8 % 10 % 7 % Safety oriented fixed income 17 % 18 % 16 % Opportunistic fixed income 15 % 12 % 10 % Public real assets 15 % 15 % 15 % Private real assets 10 % 8 % 8 % Total 100 % 100 % 100 % Fair Value Measurements The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2019 : TVA Retirement System At September 30, 2019 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 $ 1,766 $ 1,762 $ — $ 4 Preferred securities 10 1 9 — Debt securities Corporate debt securities 1,387 — 1,382 5 Residential mortgage-backed securities 427 — 424 3 Debt securities issued by U.S. Treasury 807 807 — — Debt securities issued by foreign governments 210 — 209 1 Asset-backed securities 144 — 116 28 Debt securities issued by state/local governments 18 — 18 — Commercial mortgage-backed securities 81 — 80 1 Commingled funds measured at net asset value (3) Equity 795 — — — Debt 308 — — — Commodities 217 — — — Blended 125 — — — Institutional mutual funds 97 97 — — Cash equivalents and other short-term investments 329 1 328 — Certificates of deposit 3 — 3 — Private credit measured at net asset value (3) 78 — — — Private equity measured at net asset value (3) 891 — — — Private real estate measured at net asset value (3) 546 — — — Securities lending collateral 224 — 224 — Derivatives Futures 2 2 — — Swaps 5 — 5 — Options 1 — 1 — Foreign currency forward receivable 1 — 1 — Total assets $ 8,472 $ 2,670 $ 2,800 $ 42 Liabilities Derivatives Futures $ 4 $ 4 $ — $ — Foreign currency forward payable 1 — 1 — Swaps 12 — 12 — Options 1 — 1 — Securities sold under agreements to repurchase 118 — 118 — Total liabilities $ 136 $ 4 $ 132 $ — Notes (1) Excludes approximately $132 million in net payables associated with security purchases and sales and various other payables. (2) Excludes a $224 million payable for collateral on loaned securities in connection with TVARS's participation in securities lending programs. (3) In accordance with Subtopic 820-10, certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2018 : TVA Retirement System At September 30, 2018 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 $ 1,787 $ 1,786 $ — $ 1 Preferred securities 10 4 6 — Debt securities Corporate debt securities 1,151 — 1,148 3 Residential mortgage-backed securities 377 — 371 6 Debt securities issued by U.S. Treasury 696 696 — — Debt securities issued by foreign governments 322 — 304 18 Asset-backed securities 129 — 103 26 Debt securities issued by state/local governments 17 — 17 — Commercial mortgage-backed securities 74 — 70 4 Commingled funds measured at net asset value (3) Equity 1,175 — — — Debt 317 — — — Commodities 232 — — — Blended 109 — — — Institutional mutual funds 109 109 — — Cash equivalents and other short-term investments 466 42 424 — Certificates of deposit 2 — 2 — Private credit measured at net asset value (3) 8 — — — Private equity measured at net asset value (3) 631 — — — Private real estate measured at net asset value (3) 583 — — — Securities lending collateral 318 — 318 — Derivatives Futures 7 7 — — Swaps 8 — 8 — Foreign currency forward receivable 3 — 3 — Total assets $ 8,531 $ 2,644 $ 2,774 $ 58 Liabilities Derivatives Futures $ 3 $ 3 $ — $ — Foreign currency forward payable 3 — 3 — Options 1 — 1 — Securities sold under agreements to repurchase 108 — 108 — Total liabilities $ 115 $ 3 $ 112 $ — Notes (1) Excludes approximately $ 95 million in net payables associated with security purchases and sales and various other payables. (2) Excludes a $ 318 million payable for collateral on loaned securities in connection with TVARS's participation in securities lending programs. (3) In accordance with Subtopic 820-10, certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. 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 Fair Value Measurements Using Significant Unobservable Inputs (Level 3) Balance at October 1, 2017 $ 88 Net realized/unrealized gains (losses) (4 ) Purchases, sales, issuances, and settlements ( |
Commitments and Contingencies
Commitments and Contingencies | 12 Months Ended |
Sep. 30, 2019 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | 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 capital or operating leases. In total, these agreements provide 2,230 MW of summer net capability. The remaining terms of the agreements range up to 13 years . Additionally, TVA has contracted with regional transmission organizations to reserve 1,450 MW of transmission service to support purchases from the market and wind power purchase agreements. The remaining terms of these agreements range up to four years. TVA incurred $ 195 million , $ 188 million , and $ 178 million of expense under these power purchase and transmission service agreements during 2019 , 2018 , and 2017 , respectively. Lease-related costs under TVA's power purchase agreements not accounted for as capital leases, as well as certain leases that are accounted for as capital leases, are included in TVA's consolidated statements of operations as purchased power expense and are expensed as incurred. Under federal law, TVA is obligated to purchase power from qualifying facilities (cogenerators and small power producers). As of September 30, 2019 , there was a combined qualifying facility capacity of 263 MW from 55 different generation sources, from which TVA purchased power under this law. Membership Interests of VIE Subject to Mandatory Redemption . At September 30, 2019 , TVA had outstanding membership interests subject to mandatory redemption (including current portion) of $ 28 million issued by one of its VIEs of which it is the primary beneficiary. See Note 10 — Variable Interest Entities for additional information. At September 30, 2019 , the mandatory redemptions for each of the next five years are shown below: 2020 2021 2022 2023 2024 Membership interests of variable interest entity subject to mandatory redemption $ 3 $ 3 $ 3 $ 2 $ 1 Leases . TVA leases certain property, plant, and equipment under agreements with terms ranging from one to 38 years. TVA's rental expense for operating leases, including power purchase agreement operating leases, was $ 97 million , $ 92 million , and $ 90 million in 2019 , 2018 , and 2017 , respectively. At September 30, 2019 , the future minimum lease payments under operating leases, including purchased power agreements that are accounted for as operating leases, are shown below. Operating Leases Minimum payments due in years ending September 30 2020 $ 76 2021 75 2022 60 2023 12 2024 3 Thereafter 2 Total $ 228 At September 30, 2019 , the future minimum lease payments under capital leases shown below were included in Capital leases and Other long-term liabilities on TVA's Consolidated Balance Sheet. Capital Leases Minimum payments due in years ending September 30 2020 $ 53 2021 53 2022 53 2023 55 2024 51 Thereafter 418 Minimum annual payments 683 Less: amount representing interest (495 ) Total $ 188 Leasebacks . At September 30, 2019 and 2018 , the outstanding leaseback obligations related to CTs and QTE were $263 million and $301 million , respectively. See Note 13 — Debt and Other Obligations — Lease/Leasebacks . At September 30, 2019 , the future minimum payments under leaseback obligations are shown below. Lease/Leasebacks Minimum payments due in years ending September 30 2020 $ 50 2021 207 2022 25 2023 — 2024 — Thereafter — Total $ 282 Unfunded Loan Commitments . At September 30, 2019 , TVA's commitments under unfunded loan commitments were $7 million for 2020 . TVA has no commitments under unfunded loan commitments for 2021 through 2024 . In addition to the commitments above, TVA had contractual obligations in the form of revenue discounts related to energy prepayments. TVA recognized $ 10 million of prepayment obligations and related interest payments of $ 4 million in revenue during 2019. The arrangement ceased in 2019. See Note 1 — Summary of Significant Accounting Policies — Energy Prepayment Obligations and Note 17 — Revenue . 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 ("ANI") and provides public liability insurance coverage of $450 million for each nuclear power plant licensed to operate. If this amount is not sufficient to cover claims arising from a nuclear incident, the second level, Secondary Financial Protection, applies. • Within the Secondary Financial Protection level, the licensee of each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident of fault, up to a maximum of approximately $138 million per reactor per incident. With TVA's seven reactors, the maximum total contingent obligation per incident is $963 million . This retrospective premium is payable at a maximum rate currently set at approximately $20 million per year, per incident, per reactor. Currently, 98 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 ANI combined with the Secondary Financial Protection should provide up to approximately $14.0 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") with limits up to $2.1 billion available for a loss at any one of TVA's three sites. Some of this insurance may require the payment of retrospective premiums up to a maximum of approximately $139 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 (up to a set dollar amount per week) with maximum limits of $ 490 million per unit. This insurance policy may require the payment of retrospective premiums up to a maximum of approximately $ 46 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 12 — Asset Retirement Obligations . Nuclear Decommissioning . Provision for decommissioning costs of nuclear generating units is based on options prescribed by the NRC procedures to dismantle and decontaminate the facilities to meet the NRC criteria for license termination. At September 30, 2019 , $3.1 billion , representing the discounted value of future estimated decommissioning costs, was included in 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 maintains a NDT to provide funding for the ultimate decommissioning of its nuclear power plants. See Note 16 — Fair Value Measurements . 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 2033 - 2055, depending on the unit. It may be possible to extend the operating life of some of the units with approval from the NRC. See Note 8 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Note 12 — Asset Retirement Obligations . Non-Nuclear Decommissioning . At September 30, 2019 , $2.5 billion , representing the discounted value of future estimated decommissioning costs, was included in 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 maintains an ART to help fund the ultimate decommissioning of its non-nuclear power assets. See Note 16 — Fair Value Measurements . Estimates involved in determining if additional funding will be made to the ART include inflation rate, rate of return projections on the fund investments, and the planned use of other sources to fund decommissioning costs. See Note 8 — Regulatory Assets and Liabilities — Non-Nuclear Decommissioning Costs and Note 12 — Asset Retirement Obligations . Environmental Matters. TVA's power 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, water quality control, and management and disposal of solid and hazardous wastes. In the future, regulations in all of these areas are expected to become more stringent. Regulations are also expected to apply to new emissions and sources, with a particular emphasis on climate change, renewable generation, and energy efficiency. TVA has incurred, and expects to continue to incur, substantial capital and operating and maintenance costs to comply with evolving environmental requirements primarily associated with, but not limited to, the operation of TVA's coal-fired generating units. Environmental requirements placed on the operation of TVA's coal-fired and other generating units will likely continue to become more restrictive over time. Litigation over emissions or discharges from coal-fired generating units is also occurring. Failure to comply with environmental and safety laws can result in TVA being subject to enforcement actions, which can lead to the imposition of significant civil liability, including fines and penalties, criminal sanctions, and/or the shutting down of non-compliant facilities . From 1970 to 2019 , TVA spent approximately $ 6.8 billion to reduce emissions from its power plants, including $ 17 million , $ 62 million , and $ 206 million in 2019 , 2018 , and 2017 , respectively, on clean air controls. TVA estimates that compliance with existing and future Clean Air Act ("CAA") requirements (excluding greenhouse gas ("GHG") requirements) could lead to costs of $ 142 million from 2020 to 2024 , which include existing controls capital projects and air operations and maintenance projects. TVA also estimates additional expenditures of approximately $1.2 billion from 2020 to 2024 relating to TVA's CCR conversion program, not including costs related to the Gallatin lawsuits, as well as expenditures of approximately $ 278 million from 2020 to 2024 relating to compliance with Clean Water Act requirements. Future costs could differ from these estimates if new environmental laws or regulations become applicable to TVA or the facilities it operates, or if existing environmental laws or regulations are revised or reinterpreted. There could also be costs that cannot reasonably be predicted at this time, due to uncertainty of actions, that could increase these estimates. Liability for releases and cleanup of hazardous substances is primarily regulated by the federal Comprehensive Environmental Response, Compensation, and Liability Act ("CERCLA") , and other federal and parallel state statutes. In a manner similar to many other industries and power systems, TVA has generated or used hazardous substances over the years. TVA operations at some facilities have resulted in contamination that TVA is addressing. At September 30, 2019 and 2018 , TVA's estimated liability for cleanup and similar environmental work for those sites for which sufficient information is available to develop a cost estimate was approximately $15 million and $12 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. Potential Liability Associated with Workers' Exposure to CCR Materials. In response to the 2008 ash spill at Kingston, TVA hired Jacobs Engineering Group, Inc. ("Jacobs") to oversee certain aspects of the cleanup. After the cleanup was completed, Jacobs was sued in the United States District Court for the Eastern District of Tennessee ("Eastern District") by employees of a contractor involved in the cleanup and family members of some of the employees. The plaintiffs alleged that Jacobs had failed to take or provide proper health precautions and misled workers about the health risks associated with exposure to coal fly ash, which is a CCR material. The plaintiffs alleged that exposure to the fly ash caused a variety of significant health issues and illnesses, including in some cases death. The case was split into two phases, with the first phase considering, among other issues, general causation and the second determining specific causation and damages. On November 7, 2018, a jury hearing the first phase returned a verdict in favor of the plaintiffs, including determinations that Jacobs failed to adhere to its contract with TVA or the Site Wide Safety and Health Plan in place; Jacobs failed to provide reasonable care to the plaintiffs; and Jacobs's failures were capable of causing a list of medical conditions, ranging from hypertension to cancer. On January 11, 2019, the district court referred the parties to mediation. Depending on the outcome of mediation, the litigation will proceed to the second phase on the question of whether Jacobs's failures did in fact cause the plaintiffs' alleged injuries and damages. On May 13, 2019, an additional group of contractor employees and family members filed suit against Jacobs in the Circuit Court for Roane County, Tennessee. These plaintiffs have raised similar claims to those litigated in the case referenced above. While TVA is not a party to either of these lawsuits, TVA could be contractually obligated to reimburse Jacobs for some amounts that Jacobs is required to pay. Further, TVA will continue monitoring the litigation to determine whether these or similar cases could have broader implications for the utility industry. 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, as a result of a catastrophic event or otherwise. General. At September 30, 2019 , TVA had accrued $ 14 million with respect to Legal Proceedings. Of the accrued amount, $ 12 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 . In April 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: the Sierra Club, the National Parks Conservation Association, and Our Children's Earth Foundation (collectively, the "Environmental Agreements"). They became effective in June 2011. Under the Environmental Agreements, TVA committed to (1) retire on a phased schedule 18 coal-fired units with a combined summer net dependable capability of 2,200 MW, (2) control, convert, or retire additional coal-fired units with a combined summer net dependable capability of 3,500 MW, (3) comply with annual, declining emission caps for SO 2 and NO x , (4) invest $ 290 million in certain TVA environmental projects (of which TVA had spent approximately $ 279 million as of September 30, 2019 ), (5) provide $ 60 million to Alabama, Kentucky, North Carolina, and Tennessee to fund environmental projects, and (6) pay civil penalties of $ 10 million . In exchange for these commitments, most past claims against TVA based on alleged New Source Review ("NSR") and associated violations were waived and cannot be brought against TVA. Future claims, including those for sulfuric acid mist and GHG emissions, can still be brought against TVA, and claims for increases in particulates can also be pursued at many of TVA's coal-fired units. Additionally, the Environmental Agreements do not address compliance with new laws and regulations or the cost associated with such compliance. The liabilities related to the Environmental Agreements are included in Accounts payable and accrued liabilities and Other long-term liabilities on the September 30, 2019 Consolidated Balance Sheet. 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, 2019 Consolidated Balance Sheet and will be recovered in rates in future periods. TVA has substantially completed the requirements in the Environmental Agreements related to retiring coal-fired units or installing controls on such units. Case Involving Kingston Fossil Plant . On May 7, 2019, Roane County and the Cities of Kingston and Harriman ("local governments") filed a lawsuit in the Circuit Court for Roane County, Tennessee, against TVA and Jacobs for monetary damages and unspecified injunctive relief relating to TVA's cleanup response to the 2008 ash spill at Kingston. The local governments allege that TVA and Jacobs failed to take proper measures to mitigate environmental and health risks during the cleanup response and misled the local governments and their citizens about health and environmental risks associated with exposure to coal fly ash. The local governments seek to recover monetary damages on behalf of their citizens for personal injury and property loss claims, damages for lost tax revenue, damages for increased emergency and medical response costs claims, punitive damages, and unspecified injunctive relief. On June 6, 2019, TVA removed the lawsuit to the Eastern District. TVA has filed a motion to dismiss the case. Trial has been scheduled for March 23, 2021. Class Action Lawsuit Involving Kingston Fossil Plant . On November 7, 2019, a resident of Roane County, Tennessee, filed a proposed class action lawsuit against Jacobs and TVA in the United States District Court for the Eastern District of Tennessee. The complaint alleges that the class representative and all other members of the proposed class were damaged as a result of the 2008 ash spill at Kingston and the resulting cleanup activities. The complaint alleges, among other things, that 1) TVA was negligent in its construction and operation of the Kingston CCR facility, 2) TVA and Jacobs failed to take proper measures to mitigate environmental and health risks during the cleanup response, and 3) TVA and Jacobs misled the community about health and environmental risks associated with exposure to coal fly ash. The complaint seeks monetary damages and injunctive relief in the form of an order requiring that the defendants establish a blood testing program and medical monitoring protocol, and to remediate damage to the proposed class’ properties. Lawsuit Brought by TDEC Involving Gallatin Fossil Plant CCR Facilities. In January 2015, the Tennessee Department of Environment and Conservation ("TDEC") filed a lawsuit against TVA in the Chancery Court for Davidson County, Tennessee, alleging that pollutants from Gallatin have been discharged in violation of the Tennessee Water Quality Control Act and the Tennessee Solid Waste Disposal Act. The Tennessee Scenic Rivers Association ("TSRA") and Tennessee Clean Water Network ("TCWN") were also plaintiffs. On June 13, 2019, the parties filed a consent decree with the court to resolve this matter, which the court approved and entered on July 24, 2019. Under the consent decree, TVA agreed to close the existing wet ash disposal impoundments by removal, either to an onsite landfill or to an offsite facility, which will be determined after appropriate environmental reviews. TVA may also submit a plan that allows for beneficial reuse of the CCR material. Under the consent decree, TVA must submit a removal and closure plan to TDEC and must remove the CCR material within 20 years of TDEC's approval of the plan. The consent decree does not contain penalties or any admission of fault or liability. In addition to the consent decree, TDEC entered an administrative order providing for ongoing investigation and monitoring related to a closed legacy impoundment at the site. After a five-year study period, TDEC and TVA will determine whether any additional corrective action and/or closure activities are necessary for the legacy impoundment. Lawsuit Brought by TSRA and TCWN Involving Gallatin Fossil Plant CCR Facilities . In April 2015, TSRA and TCWN filed a lawsuit against TVA in the U.S. District Court for the Middle District of Tennessee alleging that pollutants have been discharged into the Cumberland River from CCR facilities at Gallatin in violation of the Clean Water Act ("CWA") . The plaintiffs sought injunctive relief, including an order requiring TVA to relocate the CCR facilities, civil penalties of up to $37,500 per violation per day, and attorneys' fees. On August 4, 2017, the court issued a decision (the "August 2017 Order") that found TVA had discharged pollutants into the Cumberland River in the past and that the discharge was likely ongoing. On October 2, 2017, TVA appealed the August 2017 Order to the United States Court of Appeals for the Sixth Circuit ("Sixth Circuit"). On September 24, 2018, a panel of the Sixth Circuit reversed the district court decision and held that the district court erred by imposing CWA liability against TVA and that, therefore, the imposition of injunctive relief was an abuse of discretion. On April 15, 2019, the plaintiffs filed a petition with the U.S. Supreme Court ("Supreme Court") requesting that the Supreme Court accept an appeal of the Sixth Circuit's decision. The plaintiffs subsequently filed a motion requesting that the petition be dismissed. The Supreme Court granted this request on September 23, 2019, effectively ending this lawsuit. Consent Decree Involving Colbert Fossil Plant. In May 2013, the Alabama Department of Environmental Management ("ADEM") and TVA entered into a consent decree concerning alleged violations of the Alabama Water Pollution Control Act. The consent decree required, among other things, that TVA continue remediation efforts TVA had begun prior to the suit being filed and stop using an unlined landfill after a lined landfill is approved and constructed. In August 2018, the parties agreed to amend the consent decree to deal with groundwater issues identified after TVA published groundwater monitoring reports in accordance with the CCR rule. The amended consent decree requires TVA to investigate the nature and extent of any groundwater contamination, develop and implement a remedy, provide semiannual status reports to ADEM, and remedy any seeps identified during inspections. TVA also paid $100,000 to Alabama under the amended consent decree. In accordance with the amended consent decree, TVA submitted to ADEM a Comprehensive Groundwater Investigation Report on May 17, 2019, and an Assessment of Corrective Measures on July 17, 2019. Case Involving Tennessee River Boat Accident . On July 23, 2015, plaintiffs filed suit in the United States District Court for the Northern District of Alabama, seeking recovery for personal injuries sustained when the plaintiffs' boat struck a TVA transmission line which was being raised from the Tennessee River during a repair operation. The district court dismissed the case, finding that TVA's exercise of its discretion as a governmental entity in deciding how to carry out the operation barred any liability for negligence. In August 2017, the United States Court of Appeals for the Eleventh Circuit ("Eleventh Circuit") affirmed the decision. The plaintiffs petitioned the Supreme Court for review of the decision, arguing that the provision of the TVA Act which allows suit to be brought against TVA does not allow TVA to claim immunity for discretionary actions. On April 29, 2019, the Supreme Court issued its opinion reversing the judgment of the Eleventh Circuit and remanding the case to the Eleventh Circuit. On July 17, 2019, the Eleventh Circuit remanded the case to the district court for further proceedings consistent with the Supreme Court's opinion. The district court has issued a scheduling order setting the trial for February 16, 2021. Case Involving Bellefonte Nuclear Plant. On November 30, 2018, Nuclear Development, LLC, filed suit against TVA in the United States District Court for the Northern District of Alabama. The plaintiff alleges that TVA breached its agreement to sell Bellefonte to the plaintiff. The plaintiff seeks, among other things, (1) an injunction requiring TVA to maintain Bellefonte and the associated NRC permits until the case is concluded, (2) an order compelling TVA to complete the sale of Bellefonte to the plaintiff, and (3) if the court does not order TVA to complete the sale, monetary damages in excess of $ 30 million . On December 26, 2018, Nuclear Development, LLC, and TVA filed a joint stipulation with the court. Under the stipulation, Nuclear Development, LLC, withdrew its request for an expedited hearing on its injunction in exchange for TVA's agreement to continue to maintain Bellefonte in accordance with the NRC permits and to give Nuclear Development, LLC, and the court five days prior notice of any filing by TVA to terminate the permits or sell the site. TVA filed a motion to dismiss the case on February 4, 2019. On May 15, 2019, the court denied TVA's motion. Trial is currently scheduled for May 2020. |
Related Parties
Related Parties | 12 Months Ended |
Sep. 30, 2019 | |
Related Party Transactions [Abstract] | |
Related Parties | 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 currently receives no appropriations from Congress and funds its business using power system revenues, power financings, and other revenues. TVA is a source of cash to the federal government. TVA will indefinitely continue to pay a return on the outstanding $ 258 million payments to the U.S. Treasury in repayment of and as a return on the government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment") . See Note 18 — Proprietary Capital — Appropriation Investment. 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, 2020, 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 13 — 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 For the years ended, or at, September 30 2019 2018 2017 Revenue from sales of electricity $ 118 $ 122 $ 126 Other income 258 240 136 Expenditures Operating expenses 222 220 216 Additions to property, plant, and equipment 10 8 16 Cash and cash equivalents 45 46 46 Accounts receivable, net 76 60 84 Long-term accounts receivable 53 46 35 Accounts payable and accrued liabilities 69 69 71 Long-term power bonds, net — — 1 Return on Power Program Appropriation Investment 6 5 5 |
Unaudited Quarterly Financial I
Unaudited Quarterly Financial Information | 12 Months Ended |
Sep. 30, 2019 | |
Quarterly Financial Information Disclosure [Abstract] | |
Unaudited Quarterly Financial Information | A summary of the unaudited quarterly results of operations for the years 2019 and 2018 follows. This summary should be read in conjunction with the audited consolidated financial statements appearing herein. Results for interim periods may fluctuate as a result of seasonal weather conditions, changes in rates, and other factors. Unaudited Quarterly Financial Information 2019 First Second Third Fourth Total Operating revenues $ 2,725 $ 2,750 $ 2,604 $ 3,239 $ 11,318 Operating expenses 1,960 2,158 2,088 2,301 8,507 Operating income 765 592 516 938 2,811 Net income (loss) 423 241 165 588 1,417 Unaudited Quarterly Financial Information 2018 First Second Third Fourth Total Operating revenues $ 2,549 $ 2,792 $ 2,707 $ 3,185 $ 11,233 Operating expenses 1,951 2,027 1,942 2,745 8,665 Operating income 598 765 765 440 2,568 Net income (loss) 288 462 470 (101 ) 1,119 |
Revenue (Notes)
Revenue (Notes) | 12 Months Ended |
Sep. 30, 2019 | |
Revenue from Contract with Customer [Abstract] | |
Revenue Recognition, Deferred Revenue [Policy Text Block] | 17 . Revenue As described in Note 2 — Impact of New Accounting Standards and Interpretations , TVA adopted Revenue from Contracts with Customers effective October 1, 2018, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. As a result of the adoption of this standard, no cumulative effect adjustment was recorded. Additionally, comparative disclosures for 2018 operating results with the previous revenue recognition rules are not applicable as TVA's revenue recognition has not materially changed as a result of the new standard. 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 93 percent of TVA's revenue from sales of electricity is to 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. Directly served customers Directly served customers, including industrial customers, federal agencies, and other customers, take power for their own consumption. Similar to LPCs, power is delivered to a delivery point, at which time the customer takes possession and TVA recognizes revenue. For all power sales, the performance obligation to deliver power is satisfied in a series over time since the sales of electricity over the term of the customer contract are a series of distinct goods that are substantially the same and have the same pattern of transfer to the customer. TVA has no continuing performance obligations subsequent to delivery. Using the output method for revenue recognition provides a faithful depiction of the transfer of electricity as customers obtain control of the power and benefit from its use at delivery. Additionally, TVA has an enforceable right to consideration for energy delivered at any discrete point in time and will recognize revenue at an amount that reflects the consideration to which TVA is entitled for the energy delivered. The amount of revenue is based on contractual prices approved by the TVA Board. Customers are invoiced monthly for power delivered as measured by meters located at the delivery points. The net transaction price is offset by certain credits available to customers that are known at the time of billing. Examples of credits include items such as economic development credits to promote growth in the Tennessee Valley and interruptible 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, and certain other ancillary goods or services. Disaggregated Revenue In 2019 , the revenues generated from TVA's electricity sales were $11.2 billion and accounted for virtually all of TVA's revenues. TVA's 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) 2019 2018 2017 Alabama $ 1,593 $ 1,600 $ 1,524 Georgia 270 267 252 Kentucky 691 696 665 Mississippi 1,063 1,052 1,016 North Carolina 74 66 57 Tennessee 7,419 7,350 7,041 Virginia 45 48 47 Subtotal 11,155 11,079 10,602 Off-system sales 4 7 6 Revenue capitalized during pre-commercial plant operations (1) — (11 ) (22 ) Revenue from sales of electricity 11,159 11,075 10,586 Other revenues 159 158 153 Total operating revenues $ 11,318 $ 11,233 $ 10,739 Note (1) Represents revenue capitalized during pre-commercial operations of $11 million at Allen CC in 2018 and $22 million at Watts Bar Unit 2, Paradise CC, and Allen CC in 2017. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations . TVA's 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) 2019 2018 2017 Revenue from sales of electricity Local power companies $ 10,351 $ 10,262 $ 9,741 Industries directly served 686 695 735 Federal agencies and other 122 129 132 Revenue capitalized during pre-commercial plant operations (1) — (11 ) (22 ) Revenue from sales of electricity 11,159 11,075 10,586 Other revenues 159 158 153 Total operating revenues $ 11,318 $ 11,233 $ 10,739 Note (1) Represents revenue capitalized during pre-commercial operations of $11 million at Allen CC in 2018 and $22 million at Watts Bar Unit 2, Paradise CC, and Allen CC in 2017. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations . TVA and LPCs continue to work together to meet the changing needs of consumers around the Tennessee Valley. At its August 2019 meeting, the TVA Board approved a 20-year Partnership Agreement option that better aligns the length of LPC contracts with TVA's long-term commitments. These agreements are automatically extended each year after their initial effective date. Participating LPCs will receive benefits including a 3.1 percent wholesale bill credit in exchange for their long-term commitment, which enables TVA to recover its long-term financial commitments over a commensurate period. As of September 30, 2019, 131 LPCs had signed the 20-year Partnership Agreement with TVA. The number of LPCs with the contract arrangements described below, the revenues derived from such arrangements during 2019 , and the percentage of TVA's total operating revenues during 2019 represented by these revenues are summarized in the tables below: TVA Local Power Company Contracts At or for the year ended September 30, 2019 Contract Arrangements (1) Number of LPCs Revenue from Sales of Electricity to LPCs Percentage of Total Operating Revenues 20-year termination notice 131 $ 6,350 56.1 % 10-year termination notice 5 938 8.3 % 5-year termination notice 18 3,063 27.1 % Total 154 $ 10,351 91.5 % Note (1) Ordinarily, the LPCs and TVA have the same termination notice period; however, in contracts with three of the LPCs with five-year termination notices, TVA has a 10-year termination notice (which becomes a five-year termination notice if TVA loses its discretionary wholesale rate-setting authority). Two of the 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 — 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 2019 . 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 does not have any material contract assets as of September 30, 2019 . 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. Energy Prepayment Obligations. In 2004, TVA and its largest customer, MLGW, entered into an energy prepayment agreement under which MLGW prepaid TVA $1.5 billion for the future costs of electricity to be delivered by TVA to MLGW over a period of 15 years. TVA accounted for the prepayment as unearned revenue and reported the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2018 Consolidated Balance Sheet. The arrangement ceased in 2019. TVA recognized approximately $100 million of noncash revenue in each year of the arrangement as electricity was delivered to MLGW based on the ratio of units of kilowatt hours delivered to total units of kilowatt hours under contract. As of September 30, 2019 , $1.5 billion had been recognized as noncash revenue on a cumulative basis during the life of the agreement, $100 million of which was recognized as noncash revenue and a corresponding reduction in the balance of Energy prepayment obligations during 2018 . During 2019 , $10 million was recognized as noncash revenue and a corresponding reduction in the balance of Energy prepayment obligations. Discounts to account for the time value of money, which were recorded as a reduction to electricity sales, amounted to $4 million and $46 million during 2019 and 2018 , respectively. Economic Development Incentives. Under certain economic development programs, TVA offers incentives to existing and potential power customers in certain 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 $310 million and $276 million during 2019 and 2018 , 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, 2019 and 2018 , the outstanding unpaid incentives were $157 million and $145 million , respectively. These incentives may be subject to clawback provisions if the customers fail to meet certain program requirements. |
Subsequent Events Subsequent Ev
Subsequent Events Subsequent Events (Notes) | 12 Months Ended |
Sep. 30, 2019 | |
Subsequent Events [Abstract] | |
Subsequent Events [Text Block] | 25 . Subsequent Events Redemption of Debt On October 15, 2019, TVA provided notice of its intent to redeem on November 15, 2019, the following electronotes identified by their respective CUSIP numbers and maturity dates. The notes will be redeemed at 100 percent of par value. Year Issued CUSIP Coupon Rate Maturity Date Principal Outstanding 2012 88059TFH9 3.250% 2/15/2032 $ 34 2012 88059TFJ5 3.625% 3/15/2042 27 2012 88059TFK2 3.375% 4/15/2032 24 2012 88059TFL0 3.550% 5/15/2042 35 2013 88059TFM8 3.625% 2/15/2043 48 2013 88059TFN6 2.375% 2/15/2025 9 2013 88059TFP1 2.375% 2/15/2025 12 2013 88059TFQ9 3.000% 3/15/2029 16 2013 88059TFR7 3.150% 4/15/2033 12 $ 217 TDEC Regulations In October 2019, TDEC released amendments to its regulations which govern solid waste disposal facilities, including TVA’s active CCR facilities covered by a solid waste disposal permit and those which closed pursuant to a TDEC approved closure plan. Such facilities are generally subject to a 30-year post-closure care period during which the owner or operator must undertake certain activities, including monitoring and maintaining the facility. The amendments will, among other things, substantially increase the post-closure care period, require resubmittal of closure plans every 10 years, and require TVA to submit recommendations as to what activities must be performed during the extended closure period to protect human health and the environment. TVA is currently evaluating the amendments to determine their potential impact on TVA and anticipates that the costs of complying with the amendments could be material. |
Plant Closures (Notes)
Plant Closures (Notes) | 12 Months Ended |
Sep. 30, 2019 | |
Property, Plant and Equipment [Abstract] | |
Plant Retirement and Abandonment, Policy [Policy Text Block] | 6 . Plant Closures Background TVA must continuously evaluate all generating assets to ensure an optimum energy portfolio that provides safe, clean, and reliable power while maintaining flexibility and fiscal responsibility to the people of the Tennessee Valley. During its August 2018 meeting, the TVA Board approved a plan to perform assessments of Bull Run Fossil Plant ("Bull Run") and Paradise Fossil Plant ("Paradise"). These assessments included resiliency studies for fuel and transmission and financial considerations. TVA also prepared Environmental Assessments ("EAs") pursuant to the National Environmental Policy Act ("NEPA"). Results of these assessments were presented to the TVA Board at its February 2019 meeting, and the Board approved the retirement of Paradise Unit 3 by December 2020 and Bull Run by December 2023. Subsequent to the Board approval, TVA determined that Paradise would not be restarted after January 2020 due to the plant's material condition. Financial Impact As a result of TVA's decision to accelerate the retirements of Paradise and Bull Run, certain construction projects at these locations were identified as probable of abandonment or were no longer expected to be in service for greater than one year prior to the plants' retirement dates. The write-off of these projects resulted in $151 million of Operating and maintenance expense during the year ended September 30, 2019 . TVA also recognized losses of $19 million in Operating and maintenance expense related to additional materials and supplies inventory reserves and write-offs identified at Paradise during the year ended September 30, 2019 . TVA's policy is to adjust depreciation rates to reflect the most current assumptions, ensuring units will be fully depreciated by the applicable retirement dates. As a result of TVA's decision to accelerate the retirement of Paradise and Bull Run, TVA recognized an additional $566 million of accelerated depreciation for the year ended September 30, 2019 . |
Summary of Significant Accoun_2
Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Policies) | 12 Months Ended |
Sep. 30, 2019 | |
Accounting Policies [Abstract] | |
Regulatory Environmental Costs, Policy [Policy Text Block] | TDEC Regulations In October 2019, TDEC released amendments to its regulations which govern solid waste disposal facilities, including TVA’s active CCR facilities covered by a solid waste disposal permit and those which closed pursuant to a TDEC approved closure plan. Such facilities are generally subject to a 30-year post-closure care period during which the owner or operator must undertake certain activities, including monitoring and maintaining the facility. The amendments will, among other things, substantially increase the post-closure care period, require resubmittal of closure plans every 10 years, and require TVA to submit recommendations as to what activities must be performed during the extended closure period to protect human health and the environment. TVA is currently evaluating the amendments to determine their potential impact on TVA and anticipates that the costs of complying with the amendments could be material. |
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 nearly 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. 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 of Directors (the "TVA Board") as authorized by the Tennessee Valley Authority Act of 1933 (the "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 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 business. TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment with the 2014 payment; therefore, this item 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 ( 2019 , 2018 , 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 any of the other factors described above cease to be applicable, TVA would no longer be considered to be a regulated entity and would be required to write off these costs. All regulatory asset write offs would be required to be recognized in earnings in the period in which future recovery ceases to be probable. |
Basis of Presentation | Basis of Presentation The accompanying consolidated financial statements, which have been prepared in accordance with GAAP, include the accounts of TVA, wholly-owned direct subsidiaries, and variable interest entities ("VIE") of which TVA is the primary beneficiary. See Note 9 — Asset Acquisitions and Note 10 — 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. |
Reclassifications | Reclassifications Certain historical amounts have been reclassified in the accompanying consolidated financial statements to the current presentation. TVA reclassified $ 256 million and $ 758 million of net periodic benefit costs from Operating and maintenance expense to Other net periodic benefit cost in the Consolidated Statements of Operations for the years ending September 30, 2018 and 2017 , respectively, as a result of the retrospective presentation of financing costs due to the implementation of the new accounting standard for defined benefit plan costs effective for TVA October 1, 2018. TVA also reclassified $13 million from Restricted cash and cash equivalents to Other long-term assets on the Consolidated Balance Sheet at September 30, 2018. In the September 30, 2018 , Consolidated Statements of Cash Flows, amounts previously reported as $(30) million Fuel cost adjustment deferral, $(7) million Fuel cost tax equivalents, and $39 million Other, net were consolidated and presented as $2 million Other regulatory amortization and deferrals. Additionally, $(22) million in cash flows from operating activities previously recorded as $(9) million Accounts payable and accrued liabilities and $(13) million Regulatory asset costs were reclassified to Other, net. In cash flows from financing activities, $(5) million previously recorded as Payments to U.S. Treasury was reclassified to Other, net. In the September 30, 2017 , Consolidated Statements of Cash Flows, amounts previously reported as $98 million Fuel cost adjustment deferral, $5 million Fuel cost tax equivalents, and $40 million Other, net were consolidated and presented as $143 million Other regulatory amortization and deferrals. Additionally, $(60) million in cash flows from operating activities previously recorded as $(10) million Accounts payable and accrued liabilities and $(50) million Regulatory asset costs were reclassified to Other, net. In cash flows from financing activities, $(5) million previously recorded as Payments to U.S. Treasury was reclassified to Other, net. Additionally, as a result of the implementation of the new accounting standard for Statement of Cash Flows - Classification of Certain Cash Receipts and Cash Payments, $(29) million and $(9) million were reclassified from Short-term debt issues (redemptions), net in cash flows from financing to Other, net in cash flows from operating activities in 2018 and 2017, respectively. |
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 includes 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 22 — Commitments and Contingencies — Legal Proceedings — Environmental Agreements . The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported in the Consolidated Balance Sheets and Consolidated Statements of Cash Flows: Cash, Cash Equivalents, and Restricted Cash At September 30 2019 2018 Cash and cash equivalents $ 299 $ 299 Restricted cash and cash equivalents, included in Other long-term assets 23 23 Total Cash, cash equivalents, and restricted cash $ 322 $ 322 On the September 30, 2018 and 2017, Consolidated Statements of Cash Flows, transfers between cash and restricted cash were previously reported as $12 million and $1 million , respectively, as Other, net in cash flows from operating activities. Due to the implementation of the new accounting standard for restricted cash in 2019, these amounts are not reported as cash flow activities on the Consolidated Statement of Cash Flows. |
Allowance for Uncollectible Accounts | Allowance for Uncollectible Accounts The allowance for uncollectible accounts reflects TVA's estimate of probable losses inherent in its accounts and loans receivable balances excluding the EnergyRight ® loans receivable. TVA determines the allowance based on known accounts, historical experience, and other currently available information including events such as customer bankruptcy and/or customers failing to fulfill payment arrangements after 90 days . It also reflects TVA's corporate credit department's assessment of the financial condition of customers and the credit quality of the receivables. The allowance for uncollectible accounts was less than $1 million at both September 30, 2019 and 2018 , for accounts receivable. Additionally, loans receivable of $131 million and $ 138 million at September 30, 2019 and 2018 , respectively, are included in Accounts receivable, net and Other long-term assets, for the current and long-term portions, respectively, and are reported net of allowances for uncollectible accounts of less than $ 1 million at both September 30, 2019 and 2018 , respectively. |
Energy Prepayment Obligations | Energy Prepayment Obligations In 2004, TVA and its largest customer, Memphis Light, Gas and Water Division ("MLGW") , entered into an energy prepayment agreement under which MLGW prepaid TVA $ 1.5 billion for the future costs of electricity to be delivered by TVA to MLGW over a period of 180 months . TVA accounted for the prepayment as unearned revenue and reported the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2018 Consolidated Balance Sheet. The arrangement ceased in 2019. Revenue was recognized in each year of the arrangement as electricity was delivered to MLGW based on the ratio of units of kilowatt hours delivered to total units of kilowatt hours under contract. As of September 30, 2019 , $ 1.5 billion had been recognized as non-cash revenue on a cumulative basis during the life of the agreement, $10 million and $100 million of which was recognized as non-cash revenue during 2019 and 2018 , respectively. Discounts to account for the time value of money, which are recorded as a reduction to electricity sales, amounted to $ 4 million and $ 46 million for the years ended September 30, 2019 and 2018 , respectively. 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 are recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income (expense), net. 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, and certain other ancillary goods or services. |
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 revenue from such pre-commercial generation based on the guidance provided by Federal Energy Regulatory Commission ("FERC") regulations. Watts Bar Nuclear Plant ("Watts Bar") Unit 2 commenced pre-commercial plant operations in June 2016, and commercial operations began in October 2016. In addition, the Paradise Combined Cycle Plant ("Paradise CC") commenced pre-commercial plant operations in October 2016, and commercial operations began in April 2017. The Allen Combined Cycle Plant ("Allen CC") began pre-commercial plant operations in September 2017, and began commercial operations in April 2018. Cogeneration capability at Johnsonville Combustion Turbine Unit 20 commenced pre-commercial plant operations in September 2017, and was placed in service during December 2017. Estimated revenue of $ 11 million related to these projects was capitalized to offset project costs for the year ended September 30, 2018 . TVA also capitalized related fuel costs for these construction projects of approximately $ 19 million during the year ended September 30, 2018 . No such amounts were capitalized during 2019 . |
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 Credits. 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 fair value approach. RECs created through TVA-owned asset generation are recorded at zero cost. Emission Allowances . TVA has emission allowances for sulfur dioxide ("SO 2 ") and nitrogen oxide ("NO x ") which are accounted for as inventory. The cost of specific allowances used each month is charged to operating expense based on tons of SO 2 and NO x emitted during the respective compliance periods. Allowances granted to TVA by the Environmental Protection Agency ("EPA") are recorded at zero cost. 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. In 2018, TVA started moving from a site-specific inventory management policy to a fleet-wide strategy 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. 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. 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. 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 the external depreciation studies. These studies will be updated at least every five years. Depreciation expense for the years ended September 30, 2019 , 2018 , and 2017 was $1.8 billion , $ 1.3 billion , and $ 1.3 billion , respectively. Depreciation expense expressed as a percentage of the average annual depreciable completed plant was 3.09 percent for 2019 , 2.45 percent for 2018 , and 2.49 percent for 2017 . Average depreciation rates by asset class are as follows: Property, Plant, and Equipment Depreciation Rates At September 30 2019 2018 2017 Asset Class Nuclear 2.38 2.64 2.66 Coal-fired (1) 4.96 2.32 2.33 Hydroelectric 1.61 1.57 1.58 Gas and oil-fired 3.00 2.93 3.27 Transmission 1.34 1.32 1.34 Other 7.16 5.90 6.12 Note (1) The rate for 2019 includes the acceleration of depreciation related to retiring certain coal-fired units. Coal-Fired . As a result of TVA's decision to idle or retire certain units since the previous depreciation study, TVA recognized $566 million , $ 48 million , and $ 104 million in accelerated depreciation expense related to the units during the years ended September 30, 2019 , 2018 , and 2017 , respectively. Accelerated depreciation is based on the remaining useful life of the asset at the time the decision is made to idle or retire a unit. Capital Lease Agreements. Assets recorded under capital lease agreements are included in property, plant, and equipment. These primarily consist of a natural gas lateral pipeline, power production facilities, water treatment assets, certain office equipment, and land of $ 146 million and $ 149 million at September 30, 2019 and 2018 , respectively. Amortization expense related to capital leases is included in Depreciation and amortization in TVA's statement of operations, excluding leases and other financing obligations where regulatory accounting is applied. See Note 8 — Regulatory Assets and Liabilities — Other Non-Current Regulatory Assets — Deferred Capital Leases and Other Financing Obligations. Reacquired Rights . Property, plant, and equipment includes intangible reacquired rights, net of amortization, of $200 million and $208 million as of September 30, 2019 and 2018 , respectively, related to the purchase of residual interests from lease/leaseback agreements of certain combustion turbine units. Amortization expense was $8 million , $8 million , and $4 million for 2019 , 2018 , and 2017 , respectively. See Note 9 — Asset Acquisitions . Software Costs. 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 . At September 30, 2019 and 2018 , unamortized computer software costs totaled $ 63 million and $ 53 million , respectively. Amortization expense related to capitalized computer software costs was $ 38 million , $32 million , and $26 million for 2019 , 2018 , and 2017 , respectively. Software costs that do not meet capitalization criteria are expensed as incurred. 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. See Note 6 — Plant Closures . |
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. These other property-related assets include, but are not limited to, easements and coal rights. Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site restoration. Revisions to the estimates of asset retirement obligations ("AROs") are made whenever factors indicate that the timing or amounts of estimated cash flows have changed materially. Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset. See Note 8 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs and Note 12 — Asset Retirement Obligations. To estimate its decommissioning obligation related to its nuclear generating stations, TVA uses a probability-weighted, discounted cash flow model which, on a unit-by-unit basis, considers multiple outcome scenarios that include significant estimations and assumptions. Those assumptions include (1) estimates of the cost of decommissioning, (2) the method of decommissioning and the timing of the related cash flows, (3) the license period of the nuclear plant, considering the probability of license extensions, (4) cost escalation factors, and (5) the credit adjusted risk free rate to measure the obligation at the present value of the future estimated costs. TVA has ascribed probabilities to two different decommissioning methods related to its nuclear decommissioning obligation estimate: the DECON method and the SAFSTOR method. The DECON method requires radioactive contamination to be removed from a site and safely disposed of or decontaminated to a level that permits the site to be released for unrestricted use shortly after it ceases operation. The SAFSTOR method allows nuclear facilities to be placed and maintained in a condition that allows the facilities to be safely stored and subsequently decontaminated to levels that permit release for unrestricted use. |
Blended Low-Enriched Uranium Program | Blended Low-Enriched Uranium Program Under the blended low-enriched uranium ("BLEU") program, TVA, the U.S. Department of Energy ("DOE") , and certain nuclear fuel contractors have entered into agreements providing for the DOE's surplus of enriched uranium to be blended with other uranium down to a level that allows the blended uranium to be fabricated into fuel that can be used in nuclear power plants. Under the terms of an interagency agreement between TVA and the DOE, in exchange for supplying highly enriched uranium materials to the appropriate third-party fuel processors for processing into usable BLEU fuel for TVA, the DOE participates to a degree in the savings generated by TVA's use of this blended nuclear fuel. TVA accrues an obligation with each BLEU reload batch related to the portion of the ultimate future payments estimated to be attributable to the BLEU fuel currently in use. TVA estimated DOE's portion of the cost savings from the program to be $ 166 million since 2006. The last reload of BLEU material is currently underway at Browns Ferry Nuclear Plant ("Browns Ferry") . Since 2011, total payments to the DOE amounted to approximately $ 165 million for this program. No payments were made during the year ended September 30, 2019 , and the remaining obligation recorded was $ 1 million at September 30, 2019 . Down-blend Offering for Tritium TVA, the DOE, and certain nuclear fuel contractors have entered into agreements, referred to as the Down-blend offering for Tritium, that provide for the production, processing, and storage of low-enriched uranium that is to be made using surplus DOE highly enriched uranium and other uranium. Low-enriched uranium can be fabricated into fuel for use in a nuclear power plant. Production of the low-enriched uranium began in the summer of 2019 and is contracted to continue through October 2027. Beginning October 2027, contract activity will consist of storage and flag management. Flag management ensures that the uranium is of U.S. origin, free from foreign obligations, and unencumbered by policy restrictions, so that it can be used in connection with the production of tritium. Under the terms of the interagency agreement between the DOE and TVA, the DOE will reimburse TVA for a portion of the costs of converting the highly enriched uranium to low-enriched uranium. During the year ended September 30, 2019 , TVA received $23 million in reimbursements from the DOE. At September 30, 2019 , TVA recorded $6 million in Accounts receivable, net related to this agreement. |
Investment Funds | Investment Funds Investment funds consist primarily of trust funds designated to fund decommissioning requirements (see Note 22 — Commitments and Contingencies — Decommissioning Costs ), the Supplemental Executive Retirement Plan ("SERP") (see Note 21 — Overview of Plans and Benefits — Supplemental Executive Retirement Plan ), and the Deferred Compensation Plan ("DCP") . 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, and DCP 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, and DCP funds are all classified as trading. |
Insurance | Insurance Although TVA uses private companies to administer its healthcare plans for eligible active and retired employees not covered by Medicare, TVA does not purchase health insurance. Third-party actuarial specialists assist TVA in determining certain liabilities for self-insured claims. TVA recovers the costs of claims through power rates and through adjustments to the participants' contributions to their benefit plans. These liabilities are included in Other liabilities on the Consolidated Balance Sheets. TVA sponsors an Owner Controlled Insurance Program which provides workers' compensation and liability insurance for a select group of contractors performing maintenance, modifications, outage, and new construction activities at TVA facilities. The Federal Employees' Compensation Act ("FECA") governs liability to employees for service-connected injuries. TVA purchases excess workers' compensation insurance above a self-insured retention. In addition to excess workers' compensation insurance, TVA purchases the following types of insurance: • Nuclear liability insurance; nuclear property, decommissioning, and decontamination insurance; and nuclear accidental outage insurance. See Note 22 — Commitments and Contingencies — Nuclear Insurance . • Excess liability insurance for aviation, auto, marine, and general liability exposures. • Property insurance for certain conventional (non-nuclear) assets. The insurance policies are subject to the terms and conditions of the specific policy, including deductibles or self-insured retentions. To the extent insurance would not provide either a partial or total recovery of the costs associated with a loss, TVA would have to recover any such costs through other means, including through power rates. |
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 (clean energy, renewables, distributed resources, and energy efficiency), 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 in the Consolidated Statements of Operations as they are incurred except for the recording of certain regulatory assets for retirement and removal costs. |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies Revenues (Policies) | 12 Months Ended |
Sep. 30, 2019 | |
Accounting Policies [Abstract] | |
Energy Prepayment Obligations | Energy Prepayment Obligations In 2004, TVA and its largest customer, Memphis Light, Gas and Water Division ("MLGW") , entered into an energy prepayment agreement under which MLGW prepaid TVA $ 1.5 billion for the future costs of electricity to be delivered by TVA to MLGW over a period of 180 months . TVA accounted for the prepayment as unearned revenue and reported the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2018 Consolidated Balance Sheet. The arrangement ceased in 2019. Revenue was recognized in each year of the arrangement as electricity was delivered to MLGW based on the ratio of units of kilowatt hours delivered to total units of kilowatt hours under contract. As of September 30, 2019 , $ 1.5 billion had been recognized as non-cash revenue on a cumulative basis during the life of the agreement, $10 million and $100 million of which was recognized as non-cash revenue during 2019 and 2018 , respectively. Discounts to account for the time value of money, which are recorded as a reduction to electricity sales, amounted to $ 4 million and $ 46 million for the years ended September 30, 2019 and 2018 , respectively. 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 are recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income (expense), net. 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, and certain other ancillary goods or services. |
Variable Interest Entities Vari
Variable Interest Entities Variable Interest Entities (Policies) | 12 Months Ended |
Sep. 30, 2019 | |
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract] | |
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. |
Asset Retirement Obligations As
Asset Retirement Obligations Asset Retirement Obligations (Policies) | 12 Months Ended |
Sep. 30, 2019 | |
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. These other property-related assets include, but are not limited to, easements and coal rights. Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site restoration. Revisions to the estimates of asset retirement obligations ("AROs") are made whenever factors indicate that the timing or amounts of estimated cash flows have changed materially. Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset. See Note 8 — Regulatory Assets and Liabilities — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs and Note 12 — Asset Retirement Obligations. To estimate its decommissioning obligation related to its nuclear generating stations, TVA uses a probability-weighted, discounted cash flow model which, on a unit-by-unit basis, considers multiple outcome scenarios that include significant estimations and assumptions. Those assumptions include (1) estimates of the cost of decommissioning, (2) the method of decommissioning and the timing of the related cash flows, (3) the license period of the nuclear plant, considering the probability of license extensions, (4) cost escalation factors, and (5) the credit adjusted risk free rate to measure the obligation at the present value of the future estimated costs. TVA has ascribed probabilities to two different decommissioning methods related to its nuclear decommissioning obligation estimate: the DECON method and the SAFSTOR method. The DECON method requires radioactive contamination to be removed from a site and safely disposed of or decontaminated to a level that permits the site to be released for unrestricted use shortly after it ceases operation. The SAFSTOR method allows nuclear facilities to be placed and maintained in a condition that allows the facilities to be safely stored and subsequently decontaminated to levels that permit release for unrestricted use. |
Proprietary Capital Payments to
Proprietary Capital Payments to the U.S. Treasury (Policies) | 12 Months Ended |
Sep. 30, 2019 | |
Equity [Abstract] | |
Payments to U S Treasury | Payments to the U.S. Treasury TVA paid the U.S. Treasury $ 6 million , $ 5 million , and $ 5 million in 2019 , 2018 , and 2017 , 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 2.37 percent , 2.09 percent , and 2.00 percent for 2019 , 2018 , and 2017 , respectively. |
Benefit Plans Benefit Plans (Po
Benefit Plans Benefit Plans (Policies) | 12 Months Ended |
Sep. 30, 2019 | |
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 recent plan design changes, future contributions are expected to exceed the expense calculated under U.S. GAAP. Accordingly, TVA will discontinue this regulatory accounting practice once all such deferred costs have been recovered, at which time it will recognize pension costs in accordance with U.S. GAAP. 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 remaining service period of participating employees expected to receive benefits. The current projected amortization periods of unrecognized net gain or loss is approximately 10 years for the pension plan and 12 years for the post-retirement plan. 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 have prior service costs/(credits) related to plan changes made in 2009, 2010, 2016, 2018, and 2019 with remaining amortization periods ranging from one to 10 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 . |
Summary of Significant Accoun_4
Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
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 2019 2018 2017 Asset Class Nuclear 2.38 2.64 2.66 Coal-fired (1) 4.96 2.32 2.33 Hydroelectric 1.61 1.57 1.58 Gas and oil-fired 3.00 2.93 3.27 Transmission 1.34 1.32 1.34 Other 7.16 5.90 6.12 |
Impact of New Accounting Stan_2
Impact of New Accounting Standards and Interpretations Impact of New Accounting Standards and Interpretations (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Accounting Changes and Error Corrections [Abstract] | |
Schedule of New Accounting Pronouncements and Changes in Accounting Principles | 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 2019 : Defined Benefit Costs Description This guidance changes how information about defined benefit costs for pension plans and other post-retirement benefit plans is presented in employer financial statements. The guidance requires employers that present a measure of operating income in their statement of income to include only the service cost component of net periodic pension cost and net periodic post-retirement benefit cost in operating expenses (together with other employee compensation costs). The other components of net benefit cost, including amortization of prior service cost/credit and settlement and curtailment effects, are to be included in non-operating expenses. Additionally, the guidance stipulates that only the service cost component of net benefit cost is eligible for capitalization in assets. The guidance requires retrospective presentation of the service and non-service cost components in the Consolidated Statements of Operations. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA adopted this standard on a retrospective basis for the prior periods presented resulting in a reclassification of net periodic benefit costs from Operating and maintenance expense to Other net periodic benefit cost in the Consolidated Statements of Operations of $256 million and $758 million during 2018 and 2017, respectively. There was no impact on the Consolidated Balance Sheets because TVA has historically capitalized only the service cost component, which is consistent with the new guidance. See Note 1 — Summary of Significant Accounting Policies — Reclassifications for additional details. Financial Instruments Description This guidance applies to the recognition and measurement of financial assets and liabilities. The standard requires all equity investments to be measured at fair value with changes in the fair value recognized through net income (other than those accounted for under the equity method of accounting or those that result in consolidation of the investee). The standard also amends presentation requirements related to certain changes in the fair value of a liability and eliminates certain disclosure requirements of significant assumptions for financial instruments measured at amortized cost on the balance sheet. Public entities must apply the amendments by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA currently measures all of its equity investments (other than those that result in the consolidation of the investee) at fair value, with changes in the fair value recognized through net income, unless regulatory accounting is applied. The TVA Board has authorized the use of regulatory accounting for changes in fair value of certain equity investments, and as a result, those changes in fair value are deferred as regulatory assets or liabilities. TVA currently discloses significant assumptions around its estimates of fair value for financial instruments carried at amortized cost on its consolidated balance sheet. The adoption of this standard did not have a material impact on TVA's financial condition, results of operations, or cash flows because changes in fair value accounting are recognized through regulatory accounting. Revenue from Contracts with Customers Description This guidance, including subsequent amendments, replaces the existing accounting standard and industry specific guidance for revenue recognition with a five-step model for recognizing and measuring revenue from contracts with customers. The underlying principle of the guidance is to recognize revenue related to the transfer of goods or services to customers at the amount expected to be collected. The objective of the new standard is to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within and across industries. The new standard also requires enhanced disclosures regarding the nature, amount, timing, and uncertainty of revenue and the related cash flows arising from contracts with customers. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA adopted this standard using the modified retrospective method with no material changes to the amount or timing of revenue recognition. In accordance with the modified retrospective method, TVA's previously issued financial statements have not been restated to comply with the new accounting standard. Statement of Cash Flows - Classification of Certain Cash Receipts and Cash Payments Description This standard adds or clarifies guidance on the classification of certain cash receipts and payments on the statement of cash flows as follows: debt prepayment or extinguishment costs, settlement of zero-coupon bonds, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate-owned life insurance policies and bank-owned life insurance policies, distributions received from equity method investees, beneficial interest in securitization transactions, and the application of the predominance principle to separately identifiable cash flows. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters TVA adopted this standard on a retrospective basis for the prior periods presented. The adoption of this standard resulted in a reclassification of certain cash payments of $29 million and $9 million from financing activities to operating activities shown on the Consolidated Statements of Cash Flows for 2018 and 2017, respectively. The changes did not have a material impact on TVA's financial condition and results of operations. See Note 1 — Summary of Significant Accounting Policies — Reclassifications for additional details. Statement of Cash Flows - Restricted Cash Description This guidance requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance does not provide a definition of restricted cash or restricted cash equivalents. Effective Date for TVA October 1, 2018 Effect on the Financial Statements or Other Significant Matters Adoption of this standard resulted in a change to the beginning-of-period and end-of-period cash and cash equivalents and restricted cash amounts presented on the Consolidated Statements of Cash Flows. Amounts previously reported as Other, net in cash flows from operating activities of transfers from cash and restricted cash are not reported as cash flow activities. See Note 1 — Summary of Significant Accounting Policies — Cash, Cash Equivalents, and Restricted Cash for additional details. TVA applied this standard on a retrospective basis for the prior periods presented. The following accounting standards have been issued but as of September 30, 2019 , were not effective and had not been adopted by TVA: Lease Accounting Description This guidance changes the provisions of recognition in both the lessee and lessor accounting models. The standard requires entities that lease assets ("lessees") to recognize on the balance sheet the assets and liabilities for the rights and obligations created by leases with terms of more than 12 months, while also refining the definition of a lease. In addition, lessees are required to disclose key information about the amount, timing and uncertainty of cash flows arising from leasing arrangements. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee primarily depend on its classification as a finance lease (formerly referred to as capital lease) or operating lease. The standard requires both types of leases to be recognized on the balance sheet. Operating leases will result in straight-line expense, while finance leases will result in recognition of interest expense on the lease liability separate from amortization expense. The accounting rules for the owner of assets leased by the lessee ("lessor accounting") remain relatively unchanged. The standard allows for certain practical expedients to be elected related to lease term determination, separation of lease and non-lease elements, reassessment of existing leases, and short-term leases. The standard is to be applied using a modified retrospective transition. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2019. Effect on the Financial Statements or Other Significant Matters TVA has completed its evaluation of the impact of adopting this guidance and the changes on its consolidated financial statements and related disclosures. The standard is expected to impact financial position as adoption will increase the amount of assets and liabilities recognized on TVA's Consolidated Balance Sheets approximately $200 million each. The standard is not expected to have a material impact on results of operations or cash flows as expense recognition is intended to be substantially the same as the existing standard. Practical Expedient Description Package of transition practical expedients (for leases commenced prior to adoption date; expedients must be adopted as a package) Do not need to 1) reassess whether any expired or existing contracts are leases or contain leases, 2) reassess the lease classification for any expired or existing leases, and 3) reassess initial direct costs for any existing leases. Short-term lease expedient (elect by class of underlying asset) Elect as an accounting policy to not apply the recognition requirements to short-term leases by asset class. Existing and expired land easements not previously accounted for as leases Elect to not evaluate existing or expired easements under the new guidance and carry forward current accounting treatment. Comparative reporting requirements for initial adoption Elect to apply transition requirements at adoption date, recognize cumulative effect adjustment to retained earnings in period of adoption, and not apply the new requirements to comparative periods, including disclosures. Derivatives and Hedging - Improvements to Accounting for Hedging Activities Description This guidance better aligns an entity's risk management activities and financial reporting for hedging relationships through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedge results. To meet that objective, the amendments expand and refine hedge accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2019. Effect on the Financial Statements or Other Significant Matters TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations, or cash flows. Customer's Accounting for Implementation Costs in a Cloud Arrangement That Is a Service Contract Description This guidance relates to the accounting for a customer's implementation costs in a hosting arrangement that is a service contract. The amendments align the requirements for capitalizing those implementation costs with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software and hosting arrangements that include an internal-use software license. The amendments also provide requirements for the classification of the capitalized costs and related expense and cash flows in the financial statements, the application of impairment guidance to the capitalized costs, and the application of abandonment guidance to the capitalized costs. Entities are required to apply the amendments either retrospectively or prospectively to all implementation costs incurred after the adoption date. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2020. Early adoption is permitted, and TVA plans to adopt this standard October 1, 2019, on a prospective basis. Effect on the Financial Statements or Other Significant Matters TVA does not expect any material impact on TVA's financial condition, results of operations, or cash flows after the adoption of this standard. Financial Instruments - Credit Losses Description This guidance eliminates the probable initial recognition threshold in current GAAP and, instead, requires an allowance to be recorded for all expected credit losses for certain financial assets that are not measured at fair value. The allowance for credit losses is based on historical information, current conditions, and reasonable and supportable forecasts. The new standard also makes revisions to the other than temporary impairment model for available-for-sale debt securities. Disclosures of credit quality indicators in relation to the amortized cost of financing receivables are further disaggregated by year of origination. The standard also provides a transition relief that is optional for all entities. It provides entities an option to irrevocably elect the fair value option, applied on an instrument-by-instrument basis for eligible instruments. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2020. While early adoption is permitted, TVA does not plan to adopt the standard early. Effect on the Financial Statements or Other Significant Matters TVA is evaluating the potential impact of these changes on its consolidated financial statements and related disclosures. Fair Value Measurement Disclosure Description The guidance changes certain disclosure requirements for fair value measurements. It removes certain disclosure requirements, such as the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy; the policy for timing of the transfers between levels; and the valuation processes for Level 3 fair value measurements. Some disclosure requirements are added, such as the change in unrealized gains and losses included in other comprehensive income for recurring Level 3 fair value measurements and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. Effective Date for TVA The new standard is effective for TVA's interim and annual reporting periods beginning October 1, 2020. While early adoption is permitted, TVA does not plan to adopt the standard early. Effect on the Financial Statements or Other Significant Matters TVA does not expect the adoption of this standard to have a material impact on TVA's financial condition, results of operations or cash flows. TVA is evaluating the potential impact on related disclosures. Defined Benefit Plans - Disclosure Requirements Description This guidance applies to all employers that sponsor defined benefit pension or other post-retirement plans and modifies or clarifies the disclosure requirements for those plans. The amendments in this update remove disclosures that no longer are considered cost-beneficial, clarify the specific requirements of disclosures, and add disclosure requirements identified as relevant. Entities are required to apply the amendments retrospectively. Effective Date for TVA The new standard is effective for TVA's annual reporting periods beginning October 1, 2021. While early adoption is permitted, TVA does not plan to adopt the standard early. Effect on the Financial Statements or Other Significant Matters TVA is evaluating the potential impact of these changes on its consolidated financial statements and related disclosures. |
Accounts Receivable, Net Accoun
Accounts Receivable, Net Accounts Receivable, Net (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
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 2019 2018 Power receivables $ 1,624 $ 1,570 Other receivables 115 87 Accounts receivable, net (1) $ 1,739 $ 1,657 |
Inventories, Net Inventories, N
Inventories, Net Inventories, Net (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Inventory, Net [Abstract] | |
Inventories, Net | The table below summarizes the types and amounts of TVA's inventories: Inventories, Net At September 30 2019 2018 Materials and supplies inventory $ 742 $ 725 Fuel inventory 294 266 RECs/Emission allowance inventory, net 16 14 Allowance for inventory obsolescence (53 ) (44 ) Inventories, net $ 999 $ 961 |
Net Completed Plant Net Complet
Net Completed Plant Net Completed Plant (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Property, Plant and Equipment, Net, by Type [Abstract] | |
Net Completed Plant | Net completed plant consisted of the following: Net Completed Plant At September 30 2019 2018 Cost Accumulated Depreciation Net Cost Accumulated Depreciation Net Coal-fired (1) $ 17,400 $ 12,538 $ 4,862 $ 16,482 $ 11,033 $ 5,449 Gas and oil-fired 6,054 1,562 4,492 5,990 1,459 4,531 Nuclear 25,543 11,656 13,887 25,227 11,310 13,917 Transmission 7,932 3,083 4,849 7,515 3,038 4,477 Hydroelectric 3,163 1,051 2,112 3,087 1,012 2,075 Other electrical plant 1,920 1,110 810 1,881 1,107 774 Intangible software 3 1 2 3 — 3 Multipurpose dams 900 373 527 900 367 533 Other stewardship 29 10 19 29 9 20 Total $ 62,944 $ 31,384 $ 31,560 $ 61,114 $ 29,335 $ 31,779 |
Other Long-Term Assets Other Lo
Other Long-Term Assets Other Long-Term Assets (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract] | |
Other Long-Term Assets | The table below summarizes the types and amounts of TVA's other long-term assets: Other Long-Term Assets At September 30 2019 2018 EnergyRight ® loans receivable $ 81 $ 90 Loans and other long-term receivables, net (1) 125 125 Commodity contract derivative assets (2) — 31 Restricted cash and cash equivalents (1) 23 23 Prepaid capacity payments 19 27 Other 77 66 Total other long-term assets $ 325 $ 362 |
Regulatory Assets and Liabili_2
Regulatory Assets and Liabilities Regulatory Assets and Liabilities (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
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 2019 2018 Current regulatory assets Unrealized losses on interest rate derivatives $ 89 $ 73 Unrealized losses on commodity derivatives 39 4 Environmental agreements — 3 Gallatin coal combustion residual facilities — 38 Environmental cleanup costs - Kingston ash spill — 266 Fuel cost adjustment receivable 28 30 Total current regulatory assets 156 414 Non-current regulatory assets Deferred pension costs and other post-retirement benefits costs 4,756 3,119 Non-nuclear decommissioning costs 1,741 1,019 Unrealized losses on interest rate derivatives 1,241 692 Nuclear decommissioning costs 868 784 Unrealized losses on commodity derivatives 15 8 Environmental agreements 12 11 Gallatin coal combustion residual facilities — 861 Other non-current regulatory assets 130 118 Total non-current regulatory assets 8,763 6,612 Total regulatory assets $ 8,919 $ 7,026 Current regulatory liabilities Fuel cost adjustment tax equivalents $ 138 $ 146 Unrealized gains on commodity derivatives 12 41 Total current regulatory liabilities 150 187 Non-current regulatory liabilities Deferred other post-retirement benefits cost — 73 Unrealized gains on commodity derivatives — 31 Total non-current regulatory liabilities — 104 Total regulatory liabilities $ 150 $ 291 |
Variable Interest Entities Va_2
Variable Interest Entities Variable Interest Entities (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract] | |
Summary of Impact of VIEs on Consolidated Balance Sheets | The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG as of September 30, 2019 and 2018 , as reflected on the Consolidated Balance Sheets, are as follows: Summary of Impact of VIEs on Consolidated Balance Sheets At September 30 2019 2018 Current liabilities Accrued interest $ 11 $ 11 Accounts payable and accrued liabilities 3 2 Current maturities of long-term debt of variable interest entities 39 38 Total current liabilities 53 51 Other liabilities Other long-term liabilities 25 28 Long-term debt, net Long-term debt of variable interest entities, net 1,089 1,127 Total liabilities $ 1,167 $ 1,206 |
Other Long-Term Liabilities Oth
Other Long-Term Liabilities Other Long-Term Liabilities (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Other Liabilities, Noncurrent [Abstract] | |
Other Long-Term Liabilities | The table below summarizes the types and amounts of Other long-term liabilities: Other Long-Term Liabilities At September 30 2019 2018 Interest rate swap liabilities $ 1,676 $ 1,122 Gallatin coal combustion residual facilities liability — 862 Capital lease obligations 182 178 Currency swap liabilities 193 81 EnergyRight® financing obligation 90 102 Paradise pipeline financing obligation (1) 80 80 Accrued long-term service agreements (1) 66 74 Other (1) 203 216 Total other long-term liabilities $ 2,490 $ 2,715 |
Asset Retirement Obligations _2
Asset Retirement Obligations Asset Retirement Obligations (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Asset Retirement Obligation Activity | Asset Retirement Obligation Activity Nuclear Non-Nuclear Total Balance at September 30, 2017 $ 2,859 $ 1,445 $ 4,304 Settlements — (106 ) (106 ) Revisions in estimate — 430 430 Additional obligations — 1 1 Accretion (recorded to regulatory asset) 130 35 165 Asset disposition — (15 ) (15 ) Balance at September 30, 2018 2,989 1,790 4,779 (1) Settlements (7 ) (82 ) (89 ) Revisions in estimate — 50 50 Additional obligations 18 — 18 Gallatin CCR — 672 672 Accretion (recorded to regulatory asset) 136 50 186 Balance at September 30, 2019 $ 3,136 $ 2,480 $ 5,616 (1) Note (1) The current portions of the ARO liability in the amounts of $ 163 million a nd $ 115 million at September 30, 2019 and 2018 , respectively, are included in Accounts payable and accrued liabilities. |
Debt and Other Obligations Debt
Debt and Other Obligations Debt and Other Obligations (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
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 2019 2018 2017 Gross amount outstanding - discount notes $ 922 $ 1,217 $ 1,999 Weighted average interest rate - discount notes 2.152 % 2.045 % 1.000 % |
Debt Securities Activity | The table below summarizes the long-term debt securities activity for the years ended September 30, 2019 and 2018. Debt Securities Activity For the years ended September 30 2019 2018 Issues 2018 Series A (1) $ — $ 1,000 Discount on debt issues — (2 ) Total $ — $ 998 Redemptions/Maturities (2) Variable interest entities $ 38 $ 36 Notes payable 46 53 electronotes ® 5 52 2013 Series A 1,000 — 2009 Series B 30 29 1997 Series E — 650 2008 Series B — 1,000 Total $ 1,119 $ 1,820 Notes (1) The 2018 Series A bonds were issued at 99.8 percent of par. (2) All redemptions were at 100 percent of par. |
Debt Outstanding | Total debt outstanding at September 30, 2019 and 2018 , consisted of the following: Short-Term Debt At September 30 CUSIP or Other Identifier Maturity Call/(Put) Date Coupon Rate 2019 2018 Short-term debt, net of discounts $ 922 $ 1,216 Current maturities of long-term debt of VIEs issued at par 39 38 Current maturities of notes payable 23 46 Current maturities of power bonds issued at par 880591EQ1 10/15/2018 1.750% — 1,000 880591EF5 12/15/2019 3.770% 1 1 880591EF5 6/15/2020 3.770% 27 29 88059TEL1 11/15/2019 2.650% 1 1 88059TEL1 5/15/2020 2.650% 1 1 880591EV0 3/15/2020 2.250% 1,000 — Total current maturities of power bonds issued at par 1,030 1,032 Total current debt outstanding, net $ 2,014 $ 2,332 Long-Term Debt At September 30 CUSIP or Other Identifier Maturity Coupon Rate Effective Call Date 2019 Par 2018 Par Stock Exchange Listings electronotes ®(2) 5/15/2020 - 2/15/2043 2.375% - 3.625% 2/15/2015 - 2/15/2018 (5) $ 217 $ 221 None 880591EV0 3/15/2020 2.250% — 1,000 New York 880591EL2 2/15/2021 3.875% 1,500 1,500 New York 880591DC3 6/7/2021 5.805% (3) 246 (1) 261 New York, Luxembourg 880591EN8 8/15/2022 1.875% 1,000 1,000 New York 880591ER9 9/15/2024 2.875% 1,000 1,000 New York 880591CJ9 11/1/2025 6.750% 1,350 1,350 New York, Hong Kong, Luxembourg, Singapore 880591EU2 2/1/2027 2.875% 1,000 1,000 New York 880591300 (4) 6/1/2028 3.550% 273 273 New York 880591409 (4) 5/1/2029 3.360% 232 232 New York 880591DM1 5/1/2030 7.125% 1,000 1,000 New York, Luxembourg 880591DP4 6/7/2032 6.587% (3) 307 (1) 326 New York, Luxembourg 880591DV1 7/15/2033 4.700% 472 472 New York, Luxembourg 880591EF5 6/15/2034 3.770% 246 273 None 880591DX7 6/15/2035 4.650% 436 436 New York 880591CK6 4/1/2036 5.980% 121 121 New York 880591CS9 4/1/2036 5.880% 1,500 1,500 New York 880591CP5 1/15/2038 6.150% 1,000 1,000 New York 880591ED0 6/15/2038 5.500% 500 500 New York 880591EH1 9/15/2039 5.250% 2,000 2,000 New York 880591EP3 12/15/2042 3.500% 1,000 1,000 New York 880591DU3 6/7/2043 4.962% (3) 185 (1) 195 New York, Luxembourg 880591CF7 7/15/2045 6.235% 7/15/2020 140 140 New York 880591EB4 1/15/2048 4.875% 500 500 New York, Luxembourg 880591DZ2 4/1/2056 5.375% 1,000 1,000 New York 880591EJ7 9/15/2060 4.625% 1,000 1,000 New York 880591ES7 9/15/2065 4.250% 1,000 1,000 New York Subtotal 19,225 20,300 Unamortized discounts, premiums, issue costs, and other (131 ) (143 ) Total long-term outstanding power bonds, net 19,094 20,157 Long-term debt of VIEs, net 1,089 1,127 Long-term notes payable — 23 Total long-term debt, net $ 20,183 $ 21,307 Notes (1) Includes net exchange gain from currency transactions of $191 million and $ 147 million at September 30, 2019 and 2018 , respectively. (2) Includes one electronotes ® issue with partial maturities of principal for each required annual payment. (3) The coupon rate represents TVA's effective interest rate. (4) TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions. See Put and Call Options above. |
Maturities Due in the Year Ending September 30 | Maturities Due in the Year Ending September 30 2020 2021 2022 2023 2024 Thereafter Total Long-term power bonds, long-term debt of VIEs, and notes payable including current maturities (1) $ 1,092 $ 1,901 $ 1,071 $ 69 $ 1,057 $ 16,415 $ 21,605 Short-term debt, net of discounts 922 — — — — — 922 Note (1) Long-term power bonds does not include non-cash items of foreign currency exchange gain of $ 191 million , unamortized debt issue costs of $50 million , and net discount on sale of Bonds of $ 81 million . Long-term debt of VIE does not include non-cash item of unamortized debt issue costs of $ 8 million . |
Summary of Long-Term Credit Facilities | The following table provides additional information regarding TVA's funding available under the four long-term revolving credit facilities: Summary of Long-Term Credit Facilities At September 30, 2019 Maturity Date Facility Limit Letters of Credit Outstanding Cash Borrowings Availability December 2021 $ 150 $ 38 $ — $ 112 February 2022 500 500 — — June 2023 1,000 494 — 506 September 2023 1,000 310 — 690 Total $ 2,650 $ 1,342 $ — $ 1,308 |
Risk Management Activities an_2
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
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 Derivatives in Cash Flow Hedging Relationship Objective of Hedge Transaction Accounting for Derivative 2019 2018 Currency swaps To protect against changes in cash flows caused by changes in foreign currency exchange rates (exchange rate risk) Unrealized gains and losses are recorded in AOCI and reclassified to interest expense to the extent they are offset by gains and losses on the hedged transaction $ (114 ) $ 10 Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2) (1) Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income to Interest Expense For the years ended September 30 Derivatives in Cash Flow Hedging Relationship 2019 2018 Currency swaps $ (45 ) $ (26 ) Note (1) There were no ineffective portions or amounts excluded from effectiveness testing for any of the periods presented. Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $30 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 exchange gain 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 Derivative Type Objective of Derivative Accounting for Derivative Instrument 2019 2018 Interest rate swaps To fix short-term debt variable rate to a fixed rate (interest rate risk) Mark-to-Market gains and losses are recorded as regulatory assets or liabilities $ (79 ) $ (89 ) Commodity derivatives To protect against fluctuations in market prices of purchased commodities (price risk) Mark-to-Market gains and losses are recorded as regulatory assets or liabilities — (8 ) Note (1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there were no related gains (losses) recognized in income for these unrealized gains (losses) for the years ended September 30, 2019 and 2018 . Fair Values of TVA Derivatives At September 30 2019 2018 Derivatives That Receive Hedge Accounting Treatment: Balance Balance Sheet Presentation Balance Balance Sheet Presentation Currency swaps £200 million Sterling $ (90 ) Accounts payable and accrued liabilities $(6); Other long-term liabilities $(84) $ (67 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(62) £250 million Sterling (61 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(56) (12 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(7) £150 million Sterling (57 ) Accounts payable and accrued liabilities $(4); Other long-term liabilities $(53) (15 ) Accounts payable and accrued liabilities $(3); Other long-term liabilities $(12) Derivatives That Do Not Receive Hedge Accounting Treatment: Balance Balance Sheet Presentation Balance Balance Sheet Presentation Interest rate swaps $1.0 billion notional $ (1,261 ) Accounts payable and accrued liabilities $(62); Other long-term liabilities $(1,199) $ (878 ) Accounts payable and $476 million notional (498 ) Accounts payable and accrued liabilities $(24); Other long-term liabilities $(474) (317 ) Accounts payable and $42 million notional (5 ) Accounts payable and accrued liabilities $(2); Other long-term liabilities $(3) (4 ) Accounts payable and Commodity contract derivatives (41 ) Other current assets $12; Other long-term liabilities $(16); Accounts payable and accrued liabilities $(37) 60 Other current assets $41; Other long-term assets $31; Other long-term liabilities $(8); Accounts payable and accrued liabilities $(4) |
Fair Values of TVA Derivatives | Fair Values of TVA Derivatives At September 30 2019 2018 Derivatives That Receive Hedge Accounting Treatment: Balance Balance Sheet Presentation Balance Balance Sheet Presentation Currency swaps £200 million Sterling $ (90 ) Accounts payable and accrued liabilities $(6); Other long-term liabilities $(84) $ (67 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(62) £250 million Sterling (61 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(56) (12 ) Accounts payable and accrued liabilities $(5); Other long-term liabilities $(7) £150 million Sterling (57 ) Accounts payable and accrued liabilities $(4); Other long-term liabilities $(53) (15 ) Accounts payable and accrued liabilities $(3); Other long-term liabilities $(12) Derivatives That Do Not Receive Hedge Accounting Treatment: Balance Balance Sheet Presentation Balance Balance Sheet Presentation Interest rate swaps $1.0 billion notional $ (1,261 ) Accounts payable and accrued liabilities $(62); Other long-term liabilities $(1,199) $ (878 ) Accounts payable and $476 million notional (498 ) Accounts payable and accrued liabilities $(24); Other long-term liabilities $(474) (317 ) Accounts payable and $42 million notional (5 ) Accounts payable and accrued liabilities $(2); Other long-term liabilities $(3) (4 ) Accounts payable and Commodity contract derivatives (41 ) Other current assets $12; Other long-term liabilities $(16); Accounts payable and accrued liabilities $(37) 60 Other current assets $41; Other long-term assets $31; Other long-term liabilities $(8); Accounts payable and accrued liabilities $(4) |
Currency Swaps Outstanding | TVA had the following currency swaps outstanding at September 30, 2019 : Currency Swaps Outstanding At September 30, 2019 Effective Date of Currency Swap Contract Associated TVA Bond Issues Currency Exposure Expiration Date of Swap Overall Effective Cost to TVA 1999 £200 million 2021 5.81% 2001 £250 million 2032 6.59% 2003 £150 million 2043 4.96% |
Commodity Contract Derivatives | Commodity Contract Derivatives At September 30 2019 2018 Number of Contracts Notional Amount Fair Value (MtM) Number of Contracts Notional Amount Fair Value ( MtM ) Coal contract derivatives 8 9 million tons $ (4 ) 13 20 million tons $ 58 Natural gas contract derivatives 65 330 million mmBtu $ (37 ) 61 359 million mmBtu $ 2 |
Financial Trading Program Realized Gains (Losses) | TVA experienced the following realized losses related to the FTP during the periods set forth in the table below: Financial Trading Program Realized Gains (Losses) For the years ended September 30 Decrease (increase) in fuel expense 2019 2018 Natural gas $ — $ (6 ) Decrease (increase) in purchased power expense Natural gas $ — $ (2 ) |
Offsetting Assets and Liabilities | The amounts of TVA's derivative instruments as reported on the Consolidated Balance Sheets at September 30, 2019 and 2018, are shown in the table below. Derivative Assets and Liabilities At September 30, 2019 Gross Amounts of Recognized Assets/Liabilities Gross Amounts Offset in the Balance Sheet (1) Net Amounts of Assets/Liabilities Presented in the Balance Sheet (2) Assets Commodity derivatives not subject to master netting or similar arrangement $ 12 $ — $ 12 Liabilities Currency swaps (3) $ 208 $ — $ 208 Interest rate swaps (3) 1,764 — 1,764 Total derivatives subject to master netting or similar arrangement 1,972 — 1,972 Commodity derivatives not subject to master netting or similar arrangement 53 — 53 Total liabilities $ 2,025 $ — $ 2,025 At September 30, 2018 Gross Amounts of Recognized Assets/Liabilities Gross Amounts Offset in the Balance Sheet (1) Net Amounts of Assets/Liabilities Presented in the Balance Sheet (2) Assets Commodity derivatives not subject to master netting or similar arrangement $ 72 $ — $ 72 Liabilities Currency swaps (3) $ 94 $ — $ 94 Interest rate swaps (3) 1,199 — 1,199 Total derivatives subject to master netting or similar arrangement 1,293 — 1,293 Commodity derivatives not subject to master netting or similar arrangement 12 — 12 Total liabilities $ 1,305 $ — $ 1,305 Notes (1) Amounts primarily include counterparty netting of derivative contracts, margin account deposits for futures commission merchants transactions, and cash collateral received or paid in accordance with the accounting guidance for derivatives and hedging transactions. (2) There are no derivative contracts subject to a master netting arrangement or similar agreement that are not offset on the Consolidated Balance Sheets. (3) Letters of credit of approximately $1.3 billion and $ 921 million were posted as collateral at September 30, 2019 and 2018 , respectively, to partially secure the liability positions of one of the currency swaps and one of the interest rate swaps in accordance with the collateral requirements for these derivatives. |
Fair Value Measurements Fair Va
Fair Value Measurements Fair Value Measurements - (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Fair Value Disclosures [Abstract] | |
Valuation Techniques | The measurement of fair value results in classification into a hierarchy by the inputs used to determine the fair value as follows: Level 1 — Unadjusted quoted prices in active markets accessible by the reporting entity for identical assets or liabilities. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing. Level 2 — Pricing inputs other than quoted market prices included in Level 1 that are based on observable market data and that are directly or indirectly observable for substantially the full term of the asset or liability. These include quoted market prices for similar assets or liabilities, quoted market prices for identical or similar assets in markets that are not active, adjusted quoted market prices, inputs from observable data such as interest rate and yield curves, volatilities and default rates observable at commonly quoted intervals, and inputs derived from observable market data by correlation or other means. Level 3 — Pricing inputs that are unobservable, or less observable, from objective sources. Unobservable inputs are only to be used to the extent observable inputs are not available. These inputs maintain the concept of an exit price from the perspective of a market participant and should reflect assumptions of other market participants. An entity should consider all market participant assumptions that are available without unreasonable cost and effort. These are given the lowest priority and are generally used in internally developed methodologies to generate management's best estimate of the fair value when no observable market data is available. |
Unrealized Investment Gains (Losses) | TVA recorded unrealized gains and losses related to its equity and trading debt securities held during each period as follows: Unrealized Investment Gains (Losses) At or for the years ended September 30 Fund Financial Statement Presentation 2019 2018 NDT Regulatory asset $ (112 ) $ 18 ART Regulatory asset (70 ) 15 SERP Other income (expense) — 1 DCP Other income (expense) (2 ) 1 |
Fair Value Measurements | Fair Value Measurements At September 30, 2019 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 $ 464 $ — $ — $ 464 Government debt securities 279 65 — 344 Corporate debt securities — 417 — 417 Mortgage and asset-backed securities — 32 — 32 Institutional mutual funds 250 — — 250 Forward debt securities contracts — 22 — 22 Private equity funds measured at net asset value (1) — — — 140 Private real asset funds measured at net asset value (1) — — — 135 Private credit measured at net asset value (1) — — — 33 Commingled funds measured at net asset value (1) — — — 1,131 Total investments 993 536 — 2,968 Commodity contract derivatives — 7 5 12 Total $ 993 $ 543 $ 5 $ 2,980 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 (2) $ — $ 208 $ — $ 208 Interest rate swaps — 1,764 — 1,764 Commodity contract derivatives — 44 9 53 Total $ — $ 2,016 $ 9 $ 2,025 Notes (1) Certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been categorized in the fair value hierarchy. 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. (2) 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 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities. Fair Value Measurements At September 30, 2018 Quoted Prices in Active Significant Other Significant Total Assets Investments Equity securities $ 220 $ — $ — $ 220 Government debt securities 199 37 — 236 Corporate debt securities — 499 — 499 Mortgage and asset-backed securities — 50 — 50 Institutional mutual funds 126 — — 126 Forward debt securities contracts — 45 — 45 Private equity funds measured at net asset value (1) — — — 132 Private real asset funds measured at net asset value (1) — — — 124 Commingled funds measured at net asset value (1) — — — 1,430 Total investments 545 631 — 2,862 Commodity contract derivatives — 13 59 72 Total $ 545 $ 644 $ 59 $ 2,934 Quoted Prices in Active Markets for Identical Liabilities Significant Other Significant Total Liabilities Currency swaps (2) $ — $ 94 $ — $ 94 Interest rate swaps — 1,199 — 1,199 Commodity contract derivatives — 11 1 12 Total $ — $ 1,304 $ 1 $ 1,305 Notes (1) Certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been categorized in the fair value hierarchy. 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. (2) 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 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities . |
Fair Value Measurements Using Significant Unobservable Inputs | The following table presents a reconciliation of all commodity contract derivatives measured at fair value on a recurring basis using significant unobservable inputs (Level 3): Fair Value Measurements Using Significant Unobservable Inputs Commodity Contract Derivatives Balance at October 1, 2017 $ (67 ) Change in net unrealized gains (losses) deferred as regulatory assets and liabilities 125 Balance at September 30, 2018 58 Change in net unrealized gains (losses) deferred as regulatory assets and liabilities (62 ) Balance at September 30, 2019 $ (4 ) |
Quantitative Information about Level 3 Fair Value Measurements | The following table presents quantitative information related to the significant unobservable inputs used in the measurement of fair value of TVA's assets and liabilities classified as Level 3 in the fair value hierarchy: Quantitative Information about Level 3 Fair Value Measurements Fair Value at September 30, 2019 Valuation Technique(s) Unobservable Inputs Range Assets Commodity contract derivatives $ 5 Pricing model Coal supply and demand 0.4 - 0.8 billion tons/year Long-term market prices $12.10 - $94.51/ton Liabilities Commodity contract derivatives $ 9 Pricing model Coal supply and demand 0.4 - 0.8 billion tons/year Long-term market prices $12.10 - $94.51/ton Quantitative Information about Level 3 Fair Value Measurements Fair Value at September 30, 2018 Valuation Technique(s) Unobservable Inputs Range Assets Commodity contract derivatives $ 59 Pricing model Coal supply and demand 0.7 - 0.8 billion tons/year Long-term market prices $12.25 - $112.24/ton Liabilities Commodity contract derivatives $ 1 Pricing model Coal supply and demand 0.7 - 0.8 billion tons/year Long-term market prices $12.25 - $112.24/ton |
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, 2019 and 2018 , were as follows: Estimated Values of Financial Instruments Not Recorded at Fair Value At September 30, 2019 At September 30, 2018 Valuation Classification Carrying Fair Value Carrying Fair Value EnergyRight ® receivables (including current portion) Level 2 $ 101 $ 100 $ 112 $ 112 Loans and other long-term receivables, net (including current portion) Level 2 $ 131 $ 120 $ 138 $ 123 EnergyRight ® financing obligation (including current portion) Level 2 $ 113 $ 126 $ 127 $ 143 Unfunded loan commitments Level 2 $ — $ 10 $ — $ 3 Membership interests of VIEs subject to mandatory redemption (including current portion) Level 2 $ 28 $ 37 $ 30 $ 37 Long-term outstanding power bonds (including current maturities), net Level 2 $ 20,124 $ 26,059 $ 21,189 $ 23,896 Long-term debt of VIEs (including current maturities), net Level 2 $ 1,128 $ 1,371 $ 1,165 $ 1,256 Long-term notes payable (including current maturities) Level 2 $ 23 $ 23 $ 69 $ 68 |
Proprietary Capital Proprietary
Proprietary Capital Proprietary Capital (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Stockholders' Equity Note [Abstract] | |
Summary of Proprietary Capital Activity | The table below summarizes TVA's activities related to appropriated funds and retained earnings. Summary of Proprietary Capital Activity At or for the years ended September 30 2019 2018 Power Program Nonpower Programs Power Program Nonpower Programs Appropriation Investment $ 258 $ 4,351 $ 258 $ 4,351 Retained Earnings Balance at beginning of year 9,404 (3,787 ) 8,282 (3,779 ) Net income (loss) for year 1,425 (8 ) 1,127 (8 ) Return on power program appropriation investment (6 ) — (5 ) — Balance at end of year 10,823 (3,795 ) 9,404 (3,787 ) Net proprietary capital at September 30 $ 11,081 $ 556 $ 9,662 $ 564 |
Proprietary Capital Accumulated
Proprietary Capital Accumulated Other Comprehensive Income (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Equity [Abstract] | |
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block] | Accumulated Other Comprehensive Income (Loss) The items included in AOCI consist of market valuation adjustments for certain derivative instruments. See Note 15 — Risk Management Activities and Derivative Transactions . |
Other Income (Expense), Net Oth
Other Income (Expense), Net Other Income (Expense), Net (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
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 (Expense), Net For the years ended September 30 2019 2018 2017 Bellefonte deposit $ 21 $ — $ — Interest income 25 23 23 External services 13 14 14 Gains (losses) on investments 3 6 9 Miscellaneous — 7 10 Total other income (expense), net $ 62 $ 50 $ 56 |
Benefit Plans Benefit Plans (Ta
Benefit Plans Benefit Plans (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Retirement Benefits [Abstract] | |
Obligations and Funded Status | The changes in plan obligations, assets, and funded status for the years ended September 30, 2019 and 2018 , were as follows: Obligations and Funded Status For the years ended September 30 798,000,000 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Change in benefit obligation Benefit obligation at beginning of year $ 11,725 $ 12,601 $ 428 $ 494 Service cost 44 53 11 14 Interest cost 499 473 18 19 Plan participants' contributions 7 7 — — Collections (1) — — 22 25 Actuarial (gain) loss 1,756 (658 ) 78 (46 ) Plan change 7 — — (17 ) Net transfers (to) from variable fund/401(k) plan (2) 1 (26 ) — — Expenses paid (6 ) (6 ) — — Benefits paid (721 ) (719 ) (58 ) (61 ) Benefit obligation at end of year 13,312 11,725 499 428 Change in plan assets Fair value of net plan assets at beginning of year 8,003 7,989 — — Actual return on plan assets 389 454 — — Plan participants' contributions 7 7 — — Collections (1) — — 22 25 Net transfers (to) from variable fund/401(k) plan (2) 1 (26 ) — — Employer contributions 307 304 36 36 Expenses paid (6 ) (6 ) — — Benefits paid (721 ) (719 ) (58 ) (61 ) Fair value of net plan assets at end of year 7,980 8,003 — — Funded status $ (5,332 ) $ (3,722 ) $ (499 ) $ (428 ) Notes (1) Collections include retiree contributions as well as provider discounts and rebates. (2) Includes one-time transfers to the 401(k) of $23 million related to the 2018 plan amendment. |
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, 2019 and 2018 , 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 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Regulatory assets (liabilities) $ 4,731 $ 3,119 $ 25 $ (73 ) Accounts payable and accrued liabilities (5 ) (6 ) (28 ) (28 ) Pension and post-retirement benefit obligations (1) (5,327 ) (3,716 ) (471 ) (400 ) Note (1) The table above excludes $383 million and $360 million of post-employment benefit costs that are recorded in Post-retirement and post-employment benefit obligations on the Consolidated Balance Sheets at September 30, 2019 and 2018 , respectively. |
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, 2019 and 2018 , consisted of the following: Post-Retirement Benefit Costs Deferred as Regulatory Assets (Liabilities) At September 30 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Unrecognized prior service credit $ (714 ) $ (819 ) $ (135 ) $ (159 ) Unrecognized net loss 5,350 3,842 160 86 Amount capitalized due to actions of regulator 95 96 — — Total regulatory assets (liabilities) $ 4,731 $ 3,119 $ 25 $ (73 ) |
Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets | The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for the pension plan at September 30, 2019 and 2018 , were as follows: Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets At September 30 2019 2018 Projected benefit obligation $ 13,312 $ 11,725 Accumulated benefit obligation 13,246 11,659 Fair value of net plan assets 7,980 8,003 |
Components of Net Periodic Benefit Cost | The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the years ended September 30, 2019 , 2018 , and 2017 were as follows: Components of Net Periodic Benefit Cost For the years ended September 30 Pension Benefits Other Post-Retirement Benefits 2019 2018 2017 2019 2018 2017 Service cost $ 44 $ 53 $ 60 $ 11 $ 14 $ 18 Interest cost 499 473 464 18 19 21 Expected return on plan assets (477 ) (478 ) (457 ) — — — Amortization of prior service credit (99 ) (99 ) (99 ) (24 ) (22 ) (22 ) Recognized net actuarial loss 336 409 472 4 8 14 Total net periodic benefit cost as actuarially determined 303 358 440 9 19 31 Amount expensed (capitalized) due to actions of regulator 1 (54 ) 365 — — — Net periodic benefit cost $ 304 $ 304 $ 805 $ 9 $ 19 $ 31 |
Expected Amortization of Regulatory Assets in Next Fiscal Year | The amounts in the regulatory asset that are expected to be recognized as components of net periodic benefit cost during the next fiscal year are as follows: Expected Amortization of Regulatory Assets in 2020 At September 30, 2019 Pension Benefits Other Post-Retirement Benefits Total Prior service credit $ (97 ) $ (24 ) $ (121 ) Net actuarial loss 435 9 444 |
Actuarial Assumptions | TVA's reported costs of providing the plan benefits are impacted by numerous factors including the provisions of the plans, changing employee demographics, and various assumptions, the most significant of which are noted below. Actuarial Assumptions Utilized to Determine Benefit Obligations at September 30 Pension Benefits Other Post-Retirement Benefits 2019 2018 2019 2018 Discount rate 3.20 % 4.35 % 3.30 % 4.40 % Rate of compensation increase 3.50 % 3.60 % N/A N/A Cost of living adjustment (COLA) (1) 2.00 % 2.00 % 2.00 % 2.00 % Pre-Medicare eligible Initial health care cost trend rate N/A N/A 6.75 % 6.25 % Ultimate health care cost trend rate N/A N/A 5.00 % 5.00 % Year ultimate trend rate is reached N/A N/A 2027 2024 Post-Medicare eligible Initial health care cost trend rate N/A N/A — % — % Ultimate health care cost trend rate N/A N/A 4.00 % 4.00 % Year ultimate trend rate is reached N/A N/A 2023 2021 Note (1) The COLA rate is the ultimate long-term rate. Actuarial Assumptions Utilized to Determine Net Periodic Benefit Cost for the Years Ended September 30 (1) Pension Benefits Other Post-Retirement Benefits 2019 2018 2017 2019 2018 2017 Discount rate 4.35 % 3.85 % 3.65 % 4.40 % 3.95 % 3.70 % Expected return on plan assets 6.75 % 6.75 % 7.00 % N/A N/A N/A Cost of living adjustment (COLA) (2) 2.00 % 2.00 % 2.00 % 2.00 % 2.00 % 2.00 % Rate of compensation increase 3.50 % 5.34 % 5.43 % N/A N/A N/A Pre-Medicare eligible Initial health care cost trend rate N/A N/A N/A 6.25 % 6.50 % 6.50 % Ultimate health care cost trend rate N/A N/A N/A 5.00 % 5.00 % 5.00 % Year ultimate trend rate is reached N/A N/A N/A 2024 2024 2019 Post-Medicare eligible Initial health care cost trend rate N/A N/A N/A — % — % — % Ultimate health care cost trend rate N/A N/A N/A 4.00 % 4.00 % 4.00 % Year ultimate trend rate is reached N/A N/A N/A 2021 2021 2021 Notes (1) The actuarial assumptions used to determine the benefit obligations at September 30 of each year are subsequently used to determine net periodic benefit cost for the following year |
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 At September 30, 2019 Actuarial Assumption Change in Assumption Impact on 2019 Pension Cost Impact on 2019 Projected Benefit Obligation Discount rate (0.25 )% $ 16 $ 399 Rate of return on plan assets (0.25 )% 14 N/A Cost of living adjustments 0.25 % 27 261 |
Sensitivity to Changes in Assumed Health Care Cost Trend Rates | The following chart reflects the sensitivity of post-retirement benefit cost to changes in the health care trend rate: Sensitivity to Changes in Assumed Health Care Cost Trend Rates At September 30, 2019 1% Increase 1% Decrease Effect on total of service and interest cost components for the year $ 4 $ (4 ) Effect on end-of-year accumulated post-retirement benefit obligation 71 (68 ) |
Asset Holdings and Fair Value Measurements | s consistent with the asset allocation policy. At September 30, 2019 and 2018 , the asset holdings of TVARS included the following: Asset Holdings of TVARS At September 30 Plan Assets at September 30 Asset Category Target Allocation 2019 2018 Global public equity 35 % 37 % 44 % Private equity 8 % 10 % 7 % Safety oriented fixed income 17 % 18 % 16 % Opportunistic fixed income 15 % 12 % 10 % Public real assets 15 % 15 % 15 % Private real assets 10 % 8 % 8 % Total 100 % 100 % 100 % Fair Value Measurements The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2019 : TVA Retirement System At September 30, 2019 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 $ 1,766 $ 1,762 $ — $ 4 Preferred securities 10 1 9 — Debt securities Corporate debt securities 1,387 — 1,382 5 Residential mortgage-backed securities 427 — 424 3 Debt securities issued by U.S. Treasury 807 807 — — Debt securities issued by foreign governments 210 — 209 1 Asset-backed securities 144 — 116 28 Debt securities issued by state/local governments 18 — 18 — Commercial mortgage-backed securities 81 — 80 1 Commingled funds measured at net asset value (3) Equity 795 — — — Debt 308 — — — Commodities 217 — — — Blended 125 — — — Institutional mutual funds 97 97 — — Cash equivalents and other short-term investments 329 1 328 — Certificates of deposit 3 — 3 — Private credit measured at net asset value (3) 78 — — — Private equity measured at net asset value (3) 891 — — — Private real estate measured at net asset value (3) 546 — — — Securities lending collateral 224 — 224 — Derivatives Futures 2 2 — — Swaps 5 — 5 — Options 1 — 1 — Foreign currency forward receivable 1 — 1 — Total assets $ 8,472 $ 2,670 $ 2,800 $ 42 Liabilities Derivatives Futures $ 4 $ 4 $ — $ — Foreign currency forward payable 1 — 1 — Swaps 12 — 12 — Options 1 — 1 — Securities sold under agreements to repurchase 118 — 118 — Total liabilities $ 136 $ 4 $ 132 $ — Notes (1) Excludes approximately $132 million in net payables associated with security purchases and sales and various other payables. (2) Excludes a $224 million payable for collateral on loaned securities in connection with TVARS's participation in securities lending programs. (3) In accordance with Subtopic 820-10, certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2018 : TVA Retirement System At September 30, 2018 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 $ 1,787 $ 1,786 $ — $ 1 Preferred securities 10 4 6 — Debt securities Corporate debt securities 1,151 — 1,148 3 Residential mortgage-backed securities 377 — 371 6 Debt securities issued by U.S. Treasury 696 696 — — Debt securities issued by foreign governments 322 — 304 18 Asset-backed securities 129 — 103 26 Debt securities issued by state/local governments 17 — 17 — Commercial mortgage-backed securities 74 — 70 4 Commingled funds measured at net asset value (3) Equity 1,175 — — — Debt 317 — — — Commodities 232 — — — Blended 109 — — — Institutional mutual funds 109 109 — — Cash equivalents and other short-term investments 466 42 424 — Certificates of deposit 2 — 2 — Private credit measured at net asset value (3) 8 — — — Private equity measured at net asset value (3) 631 — — — Private real estate measured at net asset value (3) 583 — — — Securities lending collateral 318 — 318 — Derivatives Futures 7 7 — — Swaps 8 — 8 — Foreign currency forward receivable 3 — 3 — Total assets $ 8,531 $ 2,644 $ 2,774 $ 58 Liabilities Derivatives Futures $ 3 $ 3 $ — $ — Foreign currency forward payable 3 — 3 — Options 1 — 1 — Securities sold under agreements to repurchase 108 — 108 — Total liabilities $ 115 $ 3 $ 112 $ — Notes (1) Excludes approximately $ 95 million in net payables associated with security purchases and sales and various other payables. (2) Excludes a $ 318 million payable for collateral on loaned securities in connection with TVARS's participation in securities lending programs. |
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 Fair Value Measurements Using Significant Unobservable Inputs (Level 3) Balance at October 1, 2017 $ 88 Net realized/unrealized gains (losses) (4 ) Purchases, sales, issuances, and settlements (net) (23 ) Transfers in and/or out of Level 3 (3 ) Balance at September 30, 2018 58 Net realized/unrealized gains (losses) 4 Purchases, sales, issuances, and settlements (net) (12 ) Transfers in and/or out of Level 3 (8 ) Balance at September 30, 2019 $ 42 |
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, 2019 Pension Benefits (1) Other Post-Retirement Benefits 2020 $ 782 $ 29 2021 779 27 2022 778 25 2023 775 24 2024 771 22 2025 - 2029 3,786 111 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 related to other post-employment benefit obligations are recognized on TVA's Consolidated Balance Sheets. The current portion which represents unpaid losses and administrative fees due are in Accounts payable and accrued liabilities. The long-term portion is recognized in Post-retirement and post-employment benefit obligations. Amounts Recognized on TVA's Consolidated Balance Sheets At September 30 2019 2018 Accounts payable and accrued liabilities $ 36 $ 39 Post-retirement and post-employment benefit obligations 383 360 |
Commitments and Contingencies C
Commitments and Contingencies Commitments and Contingencies (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule of lease/leaseback future minimum payments [Table Text Block] | At September 30, 2019 , the future minimum payments under leaseback obligations are shown below. Lease/Leasebacks Minimum payments due in years ending September 30 2020 $ 50 2021 207 2022 25 2023 — 2024 — Thereafter — Total $ 282 |
Schedule of future minimum payments for membership interests subject to mandatory redemption [Table Text Block] | At September 30, 2019 , the mandatory redemptions for each of the next five years are shown below: 2020 2021 2022 2023 2024 Membership interests of variable interest entity subject to mandatory redemption $ 3 $ 3 $ 3 $ 2 $ 1 |
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block] | At September 30, 2019 , the future minimum lease payments under operating leases, including purchased power agreements that are accounted for as operating leases, are shown below. Operating Leases Minimum payments due in years ending September 30 2020 $ 76 2021 75 2022 60 2023 12 2024 3 Thereafter 2 Total $ 228 |
Energy Prepayment Obligations | In addition to the commitments above, TVA had contractual obligations in the form of revenue discounts related to energy prepayments. TVA recognized $ 10 million of prepayment obligations and related interest payments of $ 4 million in revenue during 2019. The arrangement ceased in 2019. See Note 1 — Summary of Significant Accounting Policies — Energy Prepayment Obligations and Note 17 — Revenue . |
Unfunded loan commitments | At September 30, 2019 , TVA's commitments under unfunded loan commitments were $7 million for 2020 . TVA has no commitments under unfunded loan commitments for 2021 through 2024 . |
Schedule of Future Minimum Lease Payments for Capital Leases | At September 30, 2019 , the future minimum lease payments under capital leases shown below were included in Capital leases and Other long-term liabilities on TVA's Consolidated Balance Sheet. Capital Leases Minimum payments due in years ending September 30 2020 $ 53 2021 53 2022 53 2023 55 2024 51 Thereafter 418 Minimum annual payments 683 Less: amount representing interest (495 ) Total $ 188 |
Related Parties Related Parties
Related Parties Related Parties (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Related Party Transactions [Abstract] | |
Related Party Transactions | Transactions with agencies of the federal government were as follows: Related Party Transactions For the years ended, or at, September 30 2019 2018 2017 Revenue from sales of electricity $ 118 $ 122 $ 126 Other income 258 240 136 Expenditures Operating expenses 222 220 216 Additions to property, plant, and equipment 10 8 16 Cash and cash equivalents 45 46 46 Accounts receivable, net 76 60 84 Long-term accounts receivable 53 46 35 Accounts payable and accrued liabilities 69 69 71 Long-term power bonds, net — — 1 Return on Power Program Appropriation Investment 6 5 5 |
Unaudited Quarterly Financial_2
Unaudited Quarterly Financial Information Unaudited Quarterly Financial Information (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Quarterly Financial Information Disclosure [Abstract] | |
Unaudited Quarterly Financial Information | Unaudited Quarterly Financial Information 2019 First Second Third Fourth Total Operating revenues $ 2,725 $ 2,750 $ 2,604 $ 3,239 $ 11,318 Operating expenses 1,960 2,158 2,088 2,301 8,507 Operating income 765 592 516 938 2,811 Net income (loss) 423 241 165 588 1,417 Unaudited Quarterly Financial Information 2018 First Second Third Fourth Total Operating revenues $ 2,549 $ 2,792 $ 2,707 $ 3,185 $ 11,233 Operating expenses 1,951 2,027 1,942 2,745 8,665 Operating income 598 765 765 440 2,568 Net income (loss) 288 462 470 (101 ) 1,119 |
Revenue (Tables)
Revenue (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Revenue from Contract with Customer [Abstract] | |
Revenue Recognition, Sales of Services [Policy Text Block] | 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 93 percent of TVA's revenue from sales of electricity is to 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. Directly served customers Directly served customers, including industrial customers, federal agencies, and other customers, take power for their own consumption. Similar to LPCs, power is delivered to a delivery point, at which time the customer takes possession and TVA recognizes revenue. For all power sales, the performance obligation to deliver power is satisfied in a series over time since the sales of electricity over the term of the customer contract are a series of distinct goods that are substantially the same and have the same pattern of transfer to the customer. TVA has no continuing performance obligations subsequent to delivery. Using the output method for revenue recognition provides a faithful depiction of the transfer of electricity as customers obtain control of the power and benefit from its use at delivery. Additionally, TVA has an enforceable right to consideration for energy delivered at any discrete point in time and will recognize revenue at an amount that reflects the consideration to which TVA is entitled for the energy delivered. The amount of revenue is based on contractual prices approved by the TVA Board. Customers are invoiced monthly for power delivered as measured by meters located at the delivery points. The net transaction price is offset by certain credits available to customers that are known at the time of billing. Examples of credits include items such as economic development credits to promote growth in the Tennessee Valley and interruptible 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. |
Energy Prepayment Obligations | Energy Prepayment Obligations In 2004, TVA and its largest customer, Memphis Light, Gas and Water Division ("MLGW") , entered into an energy prepayment agreement under which MLGW prepaid TVA $ 1.5 billion for the future costs of electricity to be delivered by TVA to MLGW over a period of 180 months . TVA accounted for the prepayment as unearned revenue and reported the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2018 Consolidated Balance Sheet. The arrangement ceased in 2019. Revenue was recognized in each year of the arrangement as electricity was delivered to MLGW based on the ratio of units of kilowatt hours delivered to total units of kilowatt hours under contract. As of September 30, 2019 , $ 1.5 billion had been recognized as non-cash revenue on a cumulative basis during the life of the agreement, $10 million and $100 million of which was recognized as non-cash revenue during 2019 and 2018 , respectively. Discounts to account for the time value of money, which are recorded as a reduction to electricity sales, amounted to $ 4 million and $ 46 million for the years ended September 30, 2019 and 2018 , respectively. 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 are recorded in Other revenue. Revenues that are not related to the overall mission are recorded in Other income (expense), net. 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, and certain other ancillary goods or services. |
Disaggregation of Revenue [Table Text Block] | Disaggregated Revenue In 2019 , the revenues generated from TVA's electricity sales were $11.2 billion and accounted for virtually all of TVA's revenues. TVA's 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) 2019 2018 2017 Alabama $ 1,593 $ 1,600 $ 1,524 Georgia 270 267 252 Kentucky 691 696 665 Mississippi 1,063 1,052 1,016 North Carolina 74 66 57 Tennessee 7,419 7,350 7,041 Virginia 45 48 47 Subtotal 11,155 11,079 10,602 Off-system sales 4 7 6 Revenue capitalized during pre-commercial plant operations (1) — (11 ) (22 ) Revenue from sales of electricity 11,159 11,075 10,586 Other revenues 159 158 153 Total operating revenues $ 11,318 $ 11,233 $ 10,739 Note (1) Represents revenue capitalized during pre-commercial operations of $11 million at Allen CC in 2018 and $22 million at Watts Bar Unit 2, Paradise CC, and Allen CC in 2017. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations . TVA's 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) 2019 2018 2017 Revenue from sales of electricity Local power companies $ 10,351 $ 10,262 $ 9,741 Industries directly served 686 695 735 Federal agencies and other 122 129 132 Revenue capitalized during pre-commercial plant operations (1) — (11 ) (22 ) Revenue from sales of electricity 11,159 11,075 10,586 Other revenues 159 158 153 Total operating revenues $ 11,318 $ 11,233 $ 10,739 Note (1) Represents revenue capitalized during pre-commercial operations of $11 million at Allen CC in 2018 and $22 million at Watts Bar Unit 2, Paradise CC, and Allen CC in 2017. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations . TVA and LPCs continue to work together to meet the changing needs of consumers around the Tennessee Valley. At its August 2019 meeting, the TVA Board approved a 20-year Partnership Agreement option that better aligns the length of LPC contracts with TVA's long-term commitments. These agreements are automatically extended each year after their initial effective date. Participating LPCs will receive benefits including a 3.1 percent wholesale bill credit in exchange for their long-term commitment, which enables TVA to recover its long-term financial commitments over a commensurate period. As of September 30, 2019, 131 LPCs had signed the 20-year Partnership Agreement with TVA. The number of LPCs with the contract arrangements described below, the revenues derived from such arrangements during 2019 , and the percentage of TVA's total operating revenues during 2019 represented by these revenues are summarized in the tables below: TVA Local Power Company Contracts At or for the year ended September 30, 2019 Contract Arrangements (1) Number of LPCs Revenue from Sales of Electricity to LPCs Percentage of Total Operating Revenues 20-year termination notice 131 $ 6,350 56.1 % 10-year termination notice 5 938 8.3 % 5-year termination notice 18 3,063 27.1 % Total 154 $ 10,351 91.5 % Note (1) Ordinarily, the LPCs and TVA have the same termination notice period; however, in contracts with three of the LPCs with five-year termination notices, TVA has a 10-year termination notice (which becomes a five-year termination notice if TVA loses its discretionary wholesale rate-setting authority). Two of the 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 — 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 2019 . |
Contract with Customer, Asset and Liability [Table Text Block] | 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 does not have any material contract assets as of September 30, 2019 . 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. |
Revenue Recognition, Incentives [Policy Text Block] | Economic Development Incentives. Under certain economic development programs, TVA offers incentives to existing and potential power customers in certain 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 $310 million and $276 million during 2019 and 2018 , 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, 2019 and 2018 , the outstanding unpaid incentives were $157 million and $145 million , respectively. These incentives may be subject to clawback provisions if the customers fail to meet certain program requirements. |
Energy Prepayment Obligation [Table Text Block] | Energy Prepayment Obligations. In 2004, TVA and its largest customer, MLGW, entered into an energy prepayment agreement under which MLGW prepaid TVA $1.5 billion for the future costs of electricity to be delivered by TVA to MLGW over a period of 15 years. TVA accounted for the prepayment as unearned revenue and reported the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2018 Consolidated Balance Sheet. The arrangement ceased in 2019. TVA recognized approximately $100 million of noncash revenue in each year of the arrangement as electricity was delivered to MLGW based on the ratio of units of kilowatt hours delivered to total units of kilowatt hours under contract. As of September 30, 2019 , $1.5 billion had been recognized as noncash revenue on a cumulative basis during the life of the agreement, $100 million of which was recognized as noncash revenue and a corresponding reduction in the balance of Energy prepayment obligations during 2018 . During 2019 , $10 million was recognized as noncash revenue and a corresponding reduction in the balance of Energy prepayment obligations. Discounts to account for the time value of money, which were recorded as a reduction to electricity sales, amounted to $4 million and $46 million during 2019 and 2018 , respectively. |
Subsequent Events Subsequent _2
Subsequent Events Subsequent Events (Tables) | 12 Months Ended |
Sep. 30, 2019 | |
Subsequent Events [Abstract] | |
Debt Instrument Redemption [Table Text Block] | Redemption of Debt On October 15, 2019, TVA provided notice of its intent to redeem on November 15, 2019, the following electronotes identified by their respective CUSIP numbers and maturity dates. The notes will be redeemed at 100 percent of par value. Year Issued CUSIP Coupon Rate Maturity Date Principal Outstanding 2012 88059TFH9 3.250% 2/15/2032 $ 34 2012 88059TFJ5 3.625% 3/15/2042 27 2012 88059TFK2 3.375% 4/15/2032 24 2012 88059TFL0 3.550% 5/15/2042 35 2013 88059TFM8 3.625% 2/15/2043 48 2013 88059TFN6 2.375% 2/15/2025 9 2013 88059TFP1 2.375% 2/15/2025 12 2013 88059TFQ9 3.000% 3/15/2029 16 2013 88059TFR7 3.150% 4/15/2033 12 $ 217 |
Summary of Significant Accoun_5
Summary of Significant Accounting Policies Summary of Significant Accounting Policies - General (Details) People in Millions, $ in Millions | 12 Months Ended | |||
Sep. 30, 2019USD ($)People | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Sep. 30, 2014USD ($) | |
Population of Service Area | ||||
Cash | $ 299 | $ 299 | ||
Total possible amount of BLEU payments | 166 | |||
Loans and other long-term receivables, net (including current portion) | $ 120 | 123 | ||
Population of TVA's service area (number of people) | People | 10 | |||
Allowance for uncollectible accounts - loans | 1 | |||
Revenue Capitalized During Pre-Commercial Operations | $ 0 | 11 | $ (22) | |
Fuel Cost Capitalized During Pre-Commercial Operations | 19 | |||
Recorded cost for emission allowances granted by the Environmental Protection Agency | 0 | |||
Payments attributable to blended low-enriched uranium fuel currently in use | 165 | |||
BLEU fuel obligation | 1 | |||
Reimbursements from DOE | 23 | |||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents | 322 | 322 | ||
Accounts receivable from DOE | 6 | |||
Appropriation-investment power program | 258 | 258 | $ 1,000 | |
Total | ||||
Population of Service Area | ||||
Discounts reducing electricity sales | $ 4 | 46 | ||
MLGW | ||||
Population of Service Area | ||||
Deferred revenue, revenue recognized | $ 100 |
Summary of Significant Accoun_6
Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Reclassificatons (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Reclassifications | |||
Restricted Cash | $ 12 | $ 1 | |
Defined Benefit Plan, Other Cost (Credit) | $ 258 | 256 | 758 |
Reclass of Other, net | (22) | (60) | |
Reclass of Other regulatory amortization and deferral | 2 | 143 | |
Other regulatory amortization and deferrals [Member] | |||
Reclassifications | |||
Deferred Fuel Cost | (30) | 98 | |
Reclass of fuel cost tax equivalents | (7) | 5 | |
Reclass of Other, net | 39 | 40 | |
Other, net [Member] | |||
Reclassifications | |||
Reclass of accounts payable | (9) | (10) | |
Regulatory assets costs | (13) | (50) | |
Payments to U S Treasury | (5) | (5) | |
Reclass of short-term debt issues (redemptions) | (29) | $ (9) | |
Other Long-Term Assets | |||
Reclassifications | |||
Restricted Cash | $ 13 |
Summary of Significant Accoun_7
Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Allowance for Uncollectible Accounts (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Allowance for Uncollectible Accounts | |||
Revenue Capitalized During Pre-Commercial Operations | $ 0 | $ 11 | $ (22) |
Period of time for customers to fulfill payment arrangements | 90 days | ||
Allowance for uncollectible accounts - receivables | 1 | ||
Loans receivable | $ 120 | 123 | |
Allowance for uncollectible accounts - loans | 1 | ||
Fuel Cost Capitalized During Pre-Commercial Operations | $ 19 |
Summary of Significant Accoun_8
Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Property, Plant, and Equipment, and Depreciation (Details) - USD ($) | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Property, Plant, and Equipment, and Depreciation | |||
Loans and other long-term receivables, net (including current portion) | $ 120,000,000 | $ 123,000,000 | |
Depreciation | 1,800,000,000 | $ 1,300,000,000 | $ 1,300,000,000 |
Composite depreciation rate for completed plant | 2.45% | 2.49% | |
Accelerated depreciation | 566,000,000 | $ 48,000,000 | $ 104,000,000 |
Reacquired Rights | 200,000,000 | 208,000,000 | |
Amortization of Reacquired Rights | $ 8,000,000 | 8,000,000 | 4,000,000 |
Capitalized software amortization period | 7 years | ||
Unamortized computer software costs | $ 63,000,000 | 53,000,000 | |
Amortization expense of capitalized computer software costs | $ 38,000,000 | $ 32,000,000 | $ 26,000,000 |
Nuclear | |||
Property, Plant, and Equipment, and Depreciation | |||
Composite depreciation rate for completed plant | 2.38% | 2.64% | 2.66% |
Coal-fired | |||
Property, Plant, and Equipment, and Depreciation | |||
Composite depreciation rate for completed plant | 4.96% | 2.32% | 2.33% |
Hydroelectric | |||
Property, Plant, and Equipment, and Depreciation | |||
Composite depreciation rate for completed plant | 1.61% | 1.57% | 1.58% |
Gas and oil-fired | |||
Property, Plant, and Equipment, and Depreciation | |||
Composite depreciation rate for completed plant | 3.00% | 2.93% | 3.27% |
Transmission | |||
Property, Plant, and Equipment, and Depreciation | |||
Composite depreciation rate for completed plant | 1.34% | 1.32% | 1.34% |
Other | |||
Property, Plant, and Equipment, and Depreciation | |||
Composite depreciation rate for completed plant | 7.16% | 5.90% | 6.12% |
Electricity Generation Plant, Non-Nuclear | |||
Property, Plant, and Equipment, and Depreciation | |||
Capital Leases, Net | $ 146,000,000 | $ 149,000,000 |
Summary of Significant Accoun_9
Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Energy Prepayment Obligations and Discounts on Sales (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2004 | |
Energy Prepayment Obligations and Discounts on Sales | ||||
Accounts Receivable, Allowance for Credit Loss, Current | $ 1 | |||
MLGW prepayment | $ 1,500 | |||
MLGW prepayment period | 180 months | |||
Recognition of Deferred Revenue | $ 10 | $ 100 | $ 100 | |
MLGW | ||||
Energy Prepayment Obligations and Discounts on Sales | ||||
Recognition of Deferred Revenue | $ 1,500 | |||
Deferred revenue expected recognition each year | 10 | 100 | 100 | |
Deferred revenue, revenue recognized | $ 100 | |||
Total | ||||
Energy Prepayment Obligations and Discounts on Sales | ||||
Discounts reducing electricity sales | $ 4 | $ 46 |
Impact of New Accounting Stan_3
Impact of New Accounting Standards and Interpretations Impact of New Accounting Standards and Interpretations (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||
Reclassification from Operating and maintenance expense to Other income | $ 758 | $ 179 | $ 185 |
Reclassification of net periodic benefit costs | 256 | 758 | |
Reclassification of cash receipts (payments) | $ 29 | $ 9 |
Accounts Receivable, Net Acco_2
Accounts Receivable, Net Accounts Receivable, Net (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Accounts Receivable, Net | ||
Power receivables | $ 1,624 | $ 1,570 |
Other receivables | 115 | 87 |
Allowance for uncollectible accounts | (1) | |
Accounts receivable, net | $ 1,739 | $ 1,657 |
Inventories, Net Inventories,_2
Inventories, Net Inventories, Net (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Inventories, Net | ||
Materials and supplies inventory | $ 742 | $ 725 |
Fuel inventory | 294 | 266 |
RECs/Emission allowance inventory, net | 16 | 14 |
Allowance for inventory obsolescence | (53) | (44) |
Inventories, net | $ 999 | $ 961 |
Net Completed Plant Net Compl_2
Net Completed Plant Net Completed Plant (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Completed Plant | ||
Completed plant cost | $ 62,944 | $ 61,114 |
Accumulated depreciation | 31,384 | 29,335 |
Net completed plant | 31,560 | 31,779 |
Coal-fired | ||
Completed Plant | ||
Completed plant cost | 17,400 | 16,482 |
Accumulated depreciation | 12,538 | 11,033 |
Net completed plant | 4,862 | 5,449 |
Gas and oil-fired | ||
Completed Plant | ||
Completed plant cost | 6,054 | 5,990 |
Accumulated depreciation | 1,562 | 1,459 |
Net completed plant | 4,492 | 4,531 |
Nuclear | ||
Completed Plant | ||
Completed plant cost | 25,543 | 25,227 |
Accumulated depreciation | 11,656 | 11,310 |
Net completed plant | 13,887 | 13,917 |
Transmission | ||
Completed Plant | ||
Completed plant cost | 7,932 | 7,515 |
Accumulated depreciation | 3,083 | 3,038 |
Net completed plant | 4,849 | 4,477 |
Hydroelectric | ||
Completed Plant | ||
Completed plant cost | 3,163 | 3,087 |
Accumulated depreciation | 1,051 | 1,012 |
Net completed plant | 2,112 | 2,075 |
Other electrical plant | ||
Completed Plant | ||
Completed plant cost | 1,920 | 1,881 |
Accumulated depreciation | 1,110 | 1,107 |
Net completed plant | 810 | 774 |
Computer Software, Intangible Asset [Member] | ||
Completed Plant | ||
Completed plant cost | 3 | 3 |
Accumulated depreciation | 1 | 0 |
Net completed plant | 2 | 3 |
Multipurpose dams | ||
Completed Plant | ||
Completed plant cost | 900 | 900 |
Accumulated depreciation | 373 | 367 |
Net completed plant | 527 | 533 |
Other stewardship | ||
Completed Plant | ||
Completed plant cost | 29 | 29 |
Accumulated depreciation | 10 | 9 |
Net completed plant | $ 19 | $ 20 |
Other Long-Term Assets Other _2
Other Long-Term Assets Other Long-Term Assets (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Other Long-Term Assets | |||
Restricted Cash | $ 12 | $ 1 | |
Loans and other long-term receivables | 10 | ||
EnergyRight receivables | $ 100 | 112 | |
Total other long-term assets | 325 | 362 | |
Accounts Receivable [Member] | |||
Other Long-Term Assets | |||
EnergyRight receivables | 20 | 22 | |
Other long-term assets | |||
Other Long-Term Assets | |||
EnergyRight receivables | 81 | 90 | |
Loans and other long-term receivables, net | 125 | 125 | |
Commodity contract derivative assets | 1 | 31 | |
Restricted Cash and Investments, Noncurrent | 23 | 23 | |
Prepaid capacity payments | 19 | 27 | |
Other | $ 77 | $ 66 | |
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 |
Regulatory Assets and Liabili_3
Regulatory Assets and Liabilities Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | Aug. 01, 2017 | ||
Regulatory Assets and Liabilities | |||||
Non-current regulatory liabilities | $ 0 | $ 104 | |||
Accelerated Amortization of Deferred Nuclear Generating Units and Training Costs | 857 | ||||
Accelerated recovery for Kingston ash spill | 266 | ||||
Current regulatory assets | 156 | 414 | |||
Regulatory assets | 8,763 | 6,612 | |||
Regulatory Assets | 8,919 | 7,026 | |||
Current regulatory liabilities | 150 | 187 | |||
Regulatory asset amount expensed | 261 | 2 | $ 143 | ||
Gallatin CCR | [1] | $ 672 | |||
Gallatin CCR regulatory asset | $ 900 | ||||
Period collected in rates | 15 years | ||||
Regulatory Liabilities | $ 150 | 291 | |||
Environmental Agreements | |||||
Regulatory Assets and Liabilities | |||||
Initial liability recorded | 360 | ||||
Investment in environmental agreement projects | 290 | ||||
Amount to be provided to fund environmental projects | 60 | ||||
Amount to be paid in civil penalties | $ 10 | ||||
Environmental cleanup costs - Kingston ash spill | |||||
Regulatory Assets and Liabilities | |||||
Current regulatory asset amortization period | 12 months | ||||
Energy Efficiency Projects | Environmental Agreements | |||||
Regulatory Assets and Liabilities | |||||
Regulatory asset amount expensed | $ 279 | ||||
Paid to States | Environmental Agreements | |||||
Regulatory Assets and Liabilities | |||||
Regulatory asset amount expensed | 60 | ||||
Civil Penalties | Environmental Agreements | |||||
Regulatory Assets and Liabilities | |||||
Regulatory asset amount expensed | 10 | ||||
Deferred Project Costs [Member] | |||||
Regulatory Assets and Liabilities | |||||
Gallatin coal combustion residual facilities estimated cost to cap and close | 89 | 73 | |||
Regulatory Asset | |||||
Regulatory Assets and Liabilities | |||||
Regulatory assets | 130 | 118 | |||
Removal Costs [Member] | |||||
Regulatory Assets and Liabilities | |||||
Regulatory assets | 1,241 | 692 | |||
Environmental Agreements | |||||
Regulatory Assets and Liabilities | |||||
Current regulatory assets | 0 | 3 | |||
Regulatory assets | 12 | 11 | |||
Unrealized losses on interest rate derivatives | |||||
Regulatory Assets and Liabilities | |||||
Current regulatory assets | 39 | 4 | |||
Regulatory assets | 15 | 8 | |||
Non-nuclear decommissioning costs | |||||
Regulatory Assets and Liabilities | |||||
Regulatory assets | 1,741 | 1,019 | |||
Pension Costs [Member] | |||||
Regulatory Assets and Liabilities | |||||
Regulatory assets | 4,756 | 3,119 | |||
Unrealized gains/losses on commodity derivatives | |||||
Regulatory Assets and Liabilities | |||||
Current regulatory assets | 0 | 38 | |||
Regulatory assets | 0 | 861 | |||
Deferred Fuel Costs [Member] | |||||
Regulatory Assets and Liabilities | |||||
Current regulatory assets | 28 | 30 | |||
Environmental cleanup costs - Kingston ash spill | |||||
Regulatory Assets and Liabilities | |||||
Current regulatory assets | 0 | 266 | |||
Nuclear decommissioning costs | |||||
Regulatory Assets and Liabilities | |||||
Regulatory assets | 868 | 784 | |||
Other current regulatory assets | |||||
Regulatory Assets and Liabilities | |||||
Gallatin CCR regulatory asset | 38 | ||||
Regulatory Asset | |||||
Regulatory Assets and Liabilities | |||||
Gallatin CCR regulatory asset | 861 | ||||
Unrealized gains/losses on commodity derivatives | |||||
Regulatory Assets and Liabilities | |||||
Non-current regulatory liabilities | 0 | 31 | |||
Current regulatory liabilities | 12 | 41 | |||
Deferred other post-retirement benefits cost | |||||
Regulatory Assets and Liabilities | |||||
Non-current regulatory liabilities | 0 | 73 | |||
Fuel cost adjustment tax equivalents | |||||
Regulatory Assets and Liabilities | |||||
Current regulatory liabilities | $ 138 | $ 146 | |||
[1] | (1) The current portions of the ARO liability in the amounts of $163 million and $115 million at September 30, 2019 and 2018, respectively, are included in Accounts payable and accrued liabilities. |
Asset Acquisitions and Busine_2
Asset Acquisitions and Business Combinations (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2019 | Sep. 20, 2017 | |
Business Combinations and Settlement of Preexisting Relationships [Abstract] | |||
Percentage equity interests acquired | 100.00% | ||
Total cash consideration | $ 36 | ||
Fair value of assets acquired | $ 110 | ||
Fair value of liabilities assumed | $ 78 | 74 | |
Amortization expense of SPE's acquired | 1 | ||
Loss on extinguishment | $ 3 | ||
Lease/leaseback obligations settled | 71 | ||
Reacquisition price | $ 74 |
Variable Interest Entities Va_3
Variable Interest Entities Variable Interest Entities (Details) - USD ($) $ in Millions | 12 Months Ended | ||||||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2013 | Aug. 09, 2013 | Sep. 30, 2012 | Jan. 17, 2012 | |
Liabilities | |||||||
Total liabilities | $ 1,167 | $ 1,206 | $ 1,000 | ||||
Current maturities of long-term debt of variable interest entities issued at par | 39 | 38 | |||||
Long-term debt of variable interest entities, net | 1,089 | 1,127 | |||||
VIE Financing | |||||||
Face Amount | $ 40 | $ 100 | |||||
Rate of Return SHLLC | 7.00% | ||||||
Accrued interest | $ 11 | 11 | |||||
Interest expense | 56 | 58 | $ 59 | ||||
JSCCG | |||||||
VIE Financing | |||||||
Face Amount | 900 | $ 900 | |||||
Holdco | |||||||
VIE Financing | |||||||
Face Amount | $ 100 | ||||||
SCCG | |||||||
VIE Financing | |||||||
Face Amount | $ 360 | $ 360 | |||||
Debt and Lease Obligation | $ 400 | ||||||
Accounts payable and accrued liabilities | |||||||
Liabilities | |||||||
Total liabilities | 3 | 2 | |||||
Total current liabilities | |||||||
Liabilities | |||||||
Total liabilities | 53 | 51 | |||||
Other long-term liabilities | |||||||
Liabilities | |||||||
Total liabilities | $ 25 | $ 28 |
Other Long-Term Liabilities O_2
Other Long-Term Liabilities Other Long-Term Liabilities (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | ||
Other Long-Term Liabilities | ||||
Interest rate swaps | $ 1,764 | $ 1,199 | ||
Derivative Liability | 554 | |||
Accounts Payable and Accrued Liabilities | 1 | 30 | ||
Capital lease obligations | 223 | 263 | ||
Currency swap liabilities | 208 | [1] | 94 | [2] |
EnergyRight financing obligation | 126 | 143 | ||
Non-current regulatory liabilities | 0 | 104 | ||
Total other long-term liabilities | 2,490 | 2,715 | ||
Other long-term liabilities | ||||
Other Long-Term Liabilities | ||||
Interest rate swaps | 1,676 | 1,122 | ||
Gallatin coal combustion residual facilities | 0 | 862 | ||
Capital lease obligations | 182 | 178 | ||
Currency swap liabilities | 193 | 81 | ||
EnergyRight financing obligation | 90 | 102 | ||
Environmental agreements liability | 80 | 80 | ||
Membership interests of VIE subject to mandatory redemption | 66 | 74 | ||
Other | 203 | 216 | ||
Accounts payable and accrued liabilities | ||||
Other Long-Term Liabilities | ||||
Interest rate swaps | 88 | 77 | ||
Service agreements | 12 | |||
EnergyRight financing obligation | $ 23 | 25 | ||
Accounts Payable [Member] | ||||
Other Long-Term Liabilities | ||||
Accounts Payable and Accrued Liabilities | $ 30 | |||
[1] | 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 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities. | |||
[2] | See Note 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities. |
Asset Retirement Obligations _3
Asset Retirement Obligations Asset Retirement Obligations (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Sep. 30, 2019 | Sep. 30, 2018 | Aug. 01, 2017 | ||
Liabilities Settled [Line Items] | ||||
Increase in ARO liability | $ 837 | |||
Change in estimate | [1] | 50 | $ 430 | |
Costs for asbestos | 114 | |||
Allen West ARO increase | 33 | |||
Paradise ARO increase (decrease) | 57 | |||
Allen East ARO increase (decrease) | 44 | |||
Gallatin CCR ARO increase (decrease) | 672 | |||
Additional obligations | [1] | 18 | 1 | |
Gallatin CCR | [1] | 672 | ||
Gallatin CCR regulatory asset | $ 900 | |||
Balance | [1] | 5,616 | 4,779 | |
Asset Retirement Obligation, Liabilities Settled | [1] | 89 | 106 | |
Accretion (recorded as regulatory asset) | [1] | 186 | 165 | |
Asset disposition | [1] | (15) | ||
Gain (Loss) on Disposition of Assets | 5 | |||
Amortization and Depreciation of Decontaminating and Decommissioning Assets | 144 | |||
Accounts payable and accrued liabilities | ||||
Liabilities Settled [Line Items] | ||||
Current portion of ARO | 163 | 115 | ||
Nuclear | ||||
Liabilities Settled [Line Items] | ||||
Revision of estimate (other non nuclear) | 0 | (250) | ||
Change in estimate | 0 | |||
Additional obligations | 18 | 0 | ||
Gallatin CCR | 0 | |||
Balance | 3,136 | 2,989 | ||
Asset Retirement Obligation, Liabilities Settled | 7 | 0 | ||
Accretion (recorded as regulatory asset) | 136 | 130 | ||
Asset disposition | 0 | |||
Non-nuclear | ||||
Liabilities Settled [Line Items] | ||||
Change in estimate | 50 | 430 | ||
Additional obligations | 0 | 1 | ||
Gallatin CCR | 672 | |||
Balance | 2,480 | 1,790 | ||
Asset Retirement Obligation, Liabilities Settled | 82 | 106 | ||
Accretion (recorded as regulatory asset) | $ 50 | 35 | ||
Asset disposition | $ (15) | |||
[1] | (1) The current portions of the ARO liability in the amounts of $163 million and $115 million at September 30, 2019 and 2018, respectively, are included in Accounts payable and accrued liabilities. |
Debt and Other Obligations De_2
Debt and Other Obligations Debt and Other Obligations - General (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2013 | Aug. 09, 2013 | Sep. 30, 2012 | Jan. 17, 2012 |
Debt Instrument | |||||
Interest rate | 7.10% | ||||
Debt ceiling | $ 30,000 | ||||
Face Amount | 40 | $ 100 | |||
Holdco | |||||
Debt Instrument | |||||
Face Amount | $ 100 | ||||
Holdco balloon payment upon maturity | $ 10 | ||||
SCCG | |||||
Debt Instrument | |||||
Interest rate | 3.846% | ||||
Face Amount | $ 360 | $ 360 |
Debt and Other Obligations De_3
Debt and Other Obligations Debt and Other Obligations - Secured Debt of VIEs (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | Aug. 09, 2013 | Jan. 17, 2012 |
Variable Interest Entities | ||||
Face Amount | $ 40 | $ 100 | ||
Debt Instrument, Interest Rate | 4.626% | |||
Interest rate | 7.10% | |||
Membership interests of VIE subject to mandatory redemption (including current portion) | 37 | $ 37 | $ 40 | |
Long-term debt of variable interest entities (including current maturities) | 1,371 | 1,256 | ||
Secured debt of VIEs | ||||
Variable Interest Entities | ||||
Membership interests of VIE subject to mandatory redemption (including current portion) | 28 | 30 | ||
Long-term debt of variable interest entities (including current maturities) | $ 1,100 | $ 1,165 |
Debt and Other Obligations De_4
Debt and Other Obligations Debt and Other Obligations - Secured Notes of SPEs (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 20, 2017 | Jan. 17, 2012 | Nov. 14, 2001 | Sep. 27, 2000 |
Secured notes | ||||||
Secured notes | $ 40 | $ 100 | ||||
Interest rate | 7.10% | |||||
Fair value of liabilities assumed | 78 | $ 74 | ||||
Notes Payable | 23 | $ 68 | ||||
Special purpose entity | ||||||
Secured notes | ||||||
Secured notes | $ 272 | $ 255 | ||||
Interest rate | 5.572% | 7.299% | ||||
7/20/16 Business Combination | ||||||
Secured notes | ||||||
Notes Payable | $ 20 | |||||
9/20/17 Business Combination | ||||||
Secured notes | ||||||
Notes Payable | $ 23 |
Debt and Other Obligations De_5
Debt and Other Obligations Debt and Other Obligations - Short-Term Debt (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 |
Short-Term Debt, Gross [Line Items] | |||
Short-term debt, net of discounts | $ 922 | $ 1,216 | $ 1,999 |
Short-term Borrowings Gross | $ 922 | ||
Weighted average interest rate - discount notes | 2.152% | 2.045% | 1.00% |
Short-Term Debt, Gross [Domain] | |||
Short-Term Debt, Gross [Line Items] | |||
Short-term debt, net of discounts | $ 1,217 |
Debt and Other Obligations De_6
Debt and Other Obligations Debt and Other Obligations - Put and Call Options (Details) $ in Millions | 12 Months Ended |
Sep. 30, 2019USD ($) | |
Debt Instrument | |
Amount of redeemable bond issues outstanding | $ 357 |
Call price | 100.00% |
Bond issues with survivor's option | 217 |
Amount of bonds redeemed | $ 217 |
PARRS 1998 Series D Bond | |
Debt Instrument | |
Amount of redeemable bond issues outstanding | $ 274 |
PARRS interest rate prior to rate reset | 6.75% |
PARRS interest rate after rate reset | 3.55% |
Amount of bonds redeemed | $ 301 |
PARRS 1999 Series A Bond | |
Debt Instrument | |
Amount of redeemable bond issues outstanding | $ 232 |
PARRS interest rate prior to rate reset | 6.50% |
PARRS interest rate after rate reset | 3.36% |
Amount of bonds redeemed | $ 293 |
Debt and Other Obligations De_7
Debt and Other Obligations Debt and Other Obligations - Debt Securities Activity (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | Jul. 20, 2016 | Jan. 17, 2012 | |
Debt Instrument | |||||
Issues of power bonds | $ 0 | $ 998 | $ 999 | ||
Face Amount | 40 | $ 100 | |||
Discount on debt issues | (2) | ||||
Acquisition of notes payable | 74 | ||||
Redemptions/Maturities of variable interest entities | 38 | 36 | 35 | ||
Redemptions/Maturities of power bonds | $ 1,035 | $ 1,731 | $ 1,558 | ||
Leaseback obligation settled as a result of acquisition | $ 70 | ||||
Total | |||||
Debt Instrument | |||||
Debt Instrument, Redemption Period, End Date | 1119 | 1820 | |||
Percent of par value | 100.00% | ||||
Debt of variable interest entities | |||||
Debt Instrument | |||||
Redemptions/Maturities of variable interest entities | $ 38 | $ 36 | |||
Notes Payable | |||||
Debt Instrument | |||||
Redemptions/Maturities of notes payable | 46 | 53 | |||
electronotes | |||||
Debt Instrument | |||||
Redemptions/Maturities of power bonds | 5 | 52 | |||
2013 Series A [Member] | |||||
Debt Instrument | |||||
Redemptions/Maturities of power bonds | 1,000 | 0 | |||
2009 Series B | |||||
Debt Instrument | |||||
Redemptions/Maturities of power bonds | 30 | 29 | |||
1997 Series E [Member] | |||||
Debt Instrument | |||||
Redemptions/Maturities of power bonds | 0 | 650 | |||
2008 Series B [Member] | |||||
Debt Instrument | |||||
Redemptions/Maturities of power bonds | 0 | 1,000 | |||
Total | |||||
Debt Instrument | |||||
Debt Securities Issues | $ 0 | 998 | |||
2018 Issue [Member] | |||||
Debt Instrument | |||||
Face Amount | $ 1,000 |
Debt and Other Obligations De_8
Debt and Other Obligations Debt and Other Obligations - Debt Outstanding (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||
Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2017 | Jan. 17, 2012 | ||
Short-term debt | |||||
Coupon rate | 7.10% | ||||
Short-term debt, net of discounts | $ 1,216 | $ 922 | $ 1,999 | ||
Current maturities of long-term debt of variable interest entities issued at par | 38 | 39 | |||
Current maturities of notes payable | 46 | 23 | |||
Total Current maturities of power bonds issued at par | 1,032 | 1,030 | |||
Current maturities of power bonds | 1,032 | 1,030 | |||
Total current debt outstanding, net | 2,332 | 2,014 | |||
Long-term debt | |||||
Long-term power bonds, net | 20,157 | 19,094 | |||
Long-term power bonds | [1] | 20,300 | 19,225 | ||
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net | (143) | (131) | |||
Long-term debt of variable interest entities, net | 1,127 | 1,089 | |||
Long-term notes payable | 23 | 0 | |||
Total long-term debt, net | 21,307 | 20,183 | |||
Foreign Currency Transaction Gain (Loss), before Tax | 147 | $ 191 | |||
880591EV0 [Member] | |||||
Short-term debt | |||||
Coupon rate | 2.25% | ||||
Debt Instrument, Maturity Date | Mar. 15, 2020 | ||||
Long-term debt | |||||
Long-term power bonds, net | 1,000 | $ 0 | |||
880591DX7 | |||||
Short-term debt | |||||
Coupon rate | [2] | 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 | 273 | $ 246 | |||
880591DC3 | |||||
Short-term debt | |||||
Coupon rate | 5.805% | ||||
Debt Instrument, Maturity Date | Jun. 7, 2021 | ||||
Long-term debt | |||||
Long-term power bonds, net | 261 | $ 246 | |||
880591EL2 | |||||
Short-term debt | |||||
Coupon rate | 3.875% | ||||
Debt Instrument, Maturity Date | Feb. 15, 2021 | ||||
Long-term debt | |||||
Long-term power bonds, net | 1,500 | $ 1,500 | |||
electronotes | |||||
Long-term debt | |||||
Maturity date - earliest | May 15, 2020 | ||||
Maturity date - latest | Feb. 15, 2043 | ||||
Call date - earliest | Feb. 15, 2015 | ||||
Call date - latest | Feb. 15, 2018 | ||||
Long-term power bonds, net | 221 | $ 217 | |||
880591EN8 | |||||
Short-term debt | |||||
Coupon rate | 1.875% | ||||
Debt Instrument, Maturity Date | Aug. 15, 2022 | ||||
Long-term debt | |||||
Long-term power bonds, net | 1,000 | $ 1,000 | |||
880591ER9 | |||||
Short-term debt | |||||
Coupon rate | 2.875% | ||||
Debt Instrument, Maturity Date | Sep. 15, 2024 | ||||
Long-term debt | |||||
Long-term power bonds, net | 1,000 | $ 1,000 | |||
880591CJ9 | |||||
Short-term debt | |||||
Coupon rate | 6.75% | ||||
Debt Instrument, Maturity Date | Nov. 1, 2025 | ||||
Long-term debt | |||||
Long-term power bonds, net | 1,350 | $ 1,350 | |||
880591EU2 [Member] | |||||
Short-term debt | |||||
Coupon rate | 2.875% | ||||
Debt Instrument, Maturity Date | Feb. 1, 2027 | ||||
Long-term debt | |||||
Long-term power bonds, net | 1,000 | $ 1,000 | |||
880591300 | |||||
Short-term debt | |||||
Coupon rate | 3.55% | ||||
Debt Instrument, Maturity Date | Jun. 1, 2028 | ||||
Long-term debt | |||||
Long-term power bonds, net | 273 | $ 273 | |||
880591409 | |||||
Short-term debt | |||||
Coupon rate | 3.36% | ||||
Debt Instrument, Maturity Date | May 1, 2029 | ||||
Long-term debt | |||||
Long-term power bonds, net | 232 | $ 232 | |||
880591DM1 | |||||
Short-term debt | |||||
Coupon rate | 7.125% | ||||
Debt Instrument, Maturity Date | May 1, 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. 7, 2032 | ||||
Long-term debt | |||||
Long-term power bonds, net | 326 | $ 307 | |||
880591CK6 | |||||
Short-term debt | |||||
Coupon rate | 5.98% | ||||
Debt Instrument, Maturity Date | Apr. 1, 2036 | ||||
Long-term debt | |||||
Long-term power bonds, net | 121 | $ 121 | |||
880591CS9 | |||||
Short-term debt | |||||
Coupon rate | 5.88% | ||||
Debt Instrument, Maturity Date | Apr. 1, 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. 7, 2043 | ||||
Long-term debt | |||||
Long-term power bonds, net | 195 | $ 185 | |||
880591CF7 | |||||
Short-term debt | |||||
Coupon rate | 6.235% | ||||
Debt Instrument, Maturity Date | Jul. 15, 2045 | ||||
Long-term debt | |||||
Long-term power bonds, net | 140 | $ 140 | |||
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 | [2] | 5.375% | |||
Debt Instrument, Maturity Date | Apr. 1, 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 | |||
880591EQ1 | |||||
Short-term debt | |||||
Coupon rate | 1.75% | ||||
Total Current maturities of power bonds issued at par | 1,000 | $ 0 | |||
Debt Instrument, Maturity Date | Oct. 15, 2018 | ||||
880591EF5 (6/15/2018) | |||||
Short-term debt | |||||
Total Current maturities of power bonds issued at par | 29 | $ 27 | |||
Debt Instrument, Maturity Date | Jun. 15, 2020 | ||||
880591EF5 | |||||
Short-term debt | |||||
Coupon rate | 3.77% | ||||
Total Current maturities of power bonds issued at par | 1 | $ 1 | |||
Debt Instrument, Maturity Date | Dec. 15, 2019 | ||||
88059TEL1 | |||||
Short-term debt | |||||
Coupon rate | 2.65% | ||||
Total Current maturities of power bonds issued at par | 1 | $ 1 | |||
Debt Instrument, Maturity Date | Nov. 15, 2019 | ||||
88059TEL1 (5/15/2018) | |||||
Short-term debt | |||||
Total Current maturities of power bonds issued at par | 1 | $ 1 | |||
Debt Instrument, Maturity Date | May 15, 2020 | ||||
880591EV0 [Member] | |||||
Short-term debt | |||||
Coupon rate | 2.25% | ||||
Total Current maturities of power bonds issued at par | $ 0 | $ 1,000 | |||
Debt Instrument, Maturity Date | Mar. 15, 2020 | ||||
Minimum | electronotes | |||||
Short-term debt | |||||
Coupon rate | 2.375% | ||||
Maximum | electronotes | |||||
Short-term debt | |||||
Coupon rate | 3.625% | ||||
[1] | Includes net exchange gain from currency transactions of $191 million and $147 million at September 30, 2019 and | ||||
[2] | The coupon rate represents TVA's effective interest rate. |
Debt and Other Obligations De_9
Debt and Other Obligations Debt and Other Obligations - Maturities Due (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |
Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2017 | |
Debt Instrument | |||
2018 | $ 1,092 | ||
2019 | 1,901 | ||
2020 | 1,071 | ||
2021 | 69 | ||
2022 | 1,057 | ||
Thereafter | 16,415 | ||
Total | 21,605 | ||
Short-term debt, net of discounts | $ 1,216 | 922 | $ 1,999 |
Short-term debt, net of discounts total | 922 | ||
Foreign Currency Transaction Gain (Loss), before Tax | $ 147 | 191 | |
Net discount on sale of Bonds | 81 | ||
Power bonds | |||
Debt Instrument | |||
Debt issuance costs | 50 | ||
Other long-term debt | |||
Debt Instrument | |||
Debt issuance costs | $ 8 |
Debt and Other Obligations D_10
Debt and Other Obligations Debt and Other Obligations - Credit Facility Agreements (Details) | Sep. 30, 2019USD ($)Credit_facilities | Sep. 30, 2018USD ($) |
Credit Facility Agreements | ||
Current borrowing capacity | $ 150,000,000 | |
Line of Credit | ||
Credit Facility Agreements | ||
Current borrowing capacity | 150,000,000 | |
Credit facility agreements borrowings outstanding | 0 | |
Revolving Credit Facilities | ||
Credit Facility Agreements | ||
Current borrowing capacity | 2,700,000,000 | |
Credit facility agreements borrowings outstanding | $ 0 | |
Number of revolving credit facilities | Credit_facilities | 4 | |
Revolving Credit Facility 4 | $ 150,000,000 | |
Revolving credit facility 3 | 500,000,000 | |
Revolving credit facility 1 | 1,000,000,000 | |
Revolving Credit Facility 2 | 1,000,000,000 | |
Long-term Line of Credit, Borrowings 4 | 0 | |
Long-term Line of Credit, Borrowings 3 | 0 | |
Long-term Line of Credit, Borrowings 1 | 0 | |
Long-term Line of Credit, Borrowings 2 | 0 | |
Line of Credit Facility, Remaining Borrowing Capacity 4 | 112,000,000 | |
Line of Credit Facility, Remaining Borrowing Capacity 3 | 0 | |
Line of Credit Facility, Remaining Borrowing Capacity 1 | 506,000,000 | |
Line of Credit Facility, Remaining Borrowing Capacity 2 | 690,000,000 | |
Line of Credit Facility, Remaining Borrowing Capacity | 1,308,000,000 | |
Letter of Credit | ||
Credit Facility Agreements | ||
Amount of letters of credit outstanding | 1,300,000,000 | $ 900,000,000 |
Letters of Credit Outstanding, Amount 4 | 38,000,000 | |
Letters of Credit Outstanding, Amount 3 | 500,000,000 | |
Letters of Credit Outstanding, Amount 1 | 494,000,000 | |
Letter of Credit Outstanding, Amount 2 | $ 310,000,000 |
Debt and Other Obligations D_11
Debt and Other Obligations Debt and Other Obligations - Lease/Leasebacks (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 20, 2017 | Jul. 20, 2016 |
Lease/Leasebacks [Abstract] | ||||
Percentage equity interests acquired | 100.00% | |||
Leaseback obligation settled as a result of acquisition | $ 70 | |||
CT and QTE outstanding leaseback obligation | $ 263 | $ 301 |
Accumulated Other Comprehensi_2
Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Equity [Abstract] | |||
Reclassification on cash flow hedges from AOCI to interest expense | $ (45) | $ 26 | $ (26) |
Risk Management Activities an_3
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivative Instruments That Receive Hedge Accounting Treatment (Details) - USD ($) | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Summary of Derivative Instruments That Receive Hedge Accounting Treatment | |||
Interest rate swaps | $ 1,764,000,000 | $ 1,199,000,000 | |
Net unrealized gain (loss) on future cash flow hedges | (114,000,000) | 10,000,000 | $ 59,000,000 |
Reclassification to earnings from cash flow hedges | (45,000,000) | 26,000,000 | $ (26,000,000) |
Ineffective portion excluded from testing | 0 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 30,000,000 | ||
Accounts payable and accrued liabilities | |||
Summary of Derivative Instruments That Receive Hedge Accounting Treatment | |||
Interest rate swaps | $ 88,000,000 | $ 77,000,000 |
Risk Management Activities an_4
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, 2019USD ($) | Sep. 30, 2018USD ($) | |
Derivative | ||
Unrealized gains/losses on derivatives | $ 0 | |
Change in Unrealized gains (losses) on Interest Rate Derivatives | 565,000,000 | $ (310,000,000) |
Interest rate swaps | 1,764,000,000 | 1,199,000,000 |
Interest Rate Swap | ||
Derivative | ||
Amount of gain (loss) recognized in income on derivatives | (79,000,000) | (89,000,000) |
Fair value | (498,000,000) | (317,000,000) |
Commodity Contract Derivatives | ||
Derivative | ||
Fair value | (41,000,000) | 60,000,000 |
Commodity derivatives under FTP | ||
Derivative | ||
Amount of gain (loss) recognized in income on derivatives | $ 0 | $ (8,000,000) |
Coal Contract Derivatives | ||
Derivative | ||
Number of contracts | 8 | 13 |
Notional amount | 9,000,000 | 20,000,000 |
Fair value | $ (4,000,000) | $ 58,000,000 |
Natural Gas Contract Derivatives | ||
Derivative | ||
Number of contracts | 65 | 61 |
Notional amount | 330,000,000 | 359,000,000 |
Fair value | $ (37,000,000) | $ 2,000,000 |
Accounts payable and accrued liabilities | ||
Derivative | ||
Interest rate swaps | 88,000,000 | 77,000,000 |
Accounts payable and accrued liabilities | Interest Rate Swap | ||
Derivative | ||
Fair value | (24,000,000) | (20,000,000) |
Accounts payable and accrued liabilities | Commodity Contract Derivatives | ||
Derivative | ||
Fair value | $ (37,000,000) | $ (4,000,000) |
Risk Management Activities an_5
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, 2019 | Sep. 30, 2018 | |
Derivatives, Fair Value | |||
Derivative Liability, Fair Value, Gross Liability | $ 1,972 | $ 1,293 | |
Other Credit Derivatives [Member] | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | 12 | 72 | |
Other Credit Derivatives [Member] | Other current assets | |||
Derivatives, Fair Value | |||
Fair value | 1,676 | 1,122 | |
200 million Sterling currency swap | |||
Derivatives, Fair Value | |||
Derivative Liability, Fair Value, Gross Liability | 208 | 94 | [1] |
Fair value | (90) | (67) | |
200 million Sterling currency swap | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | (84) | (62) | |
200 million Sterling currency swap | Accounts payable and accrued liabilities | |||
Derivatives, Fair Value | |||
Fair value | (6) | (5) | |
250 million Sterling currency swap | |||
Derivatives, Fair Value | |||
Fair value | (61) | (12) | |
250 million Sterling currency swap | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | (56) | (7) | |
250 million Sterling currency swap | Accounts payable and accrued liabilities | |||
Derivatives, Fair Value | |||
Fair value | (5) | (5) | |
150 million Sterling currency swap | |||
Derivatives, Fair Value | |||
Fair value | (57) | (15) | |
150 million Sterling currency swap | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | (53) | (12) | |
150 million Sterling currency swap | Accounts payable and accrued liabilities | |||
Derivatives, Fair Value | |||
Fair value | (4) | (3) | |
$1.0 billion notional interest rate swap | |||
Derivatives, Fair Value | |||
Fair value | (1,261) | (878) | |
$1.0 billion notional interest rate swap | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | (1,199) | (822) | |
$1.0 billion notional interest rate swap | Accounts payable and accrued liabilities | |||
Derivatives, Fair Value | |||
Fair value | (62) | (56) | |
$476 million notional interest rate swap | |||
Derivatives, Fair Value | |||
Fair value | (498) | (317) | |
$476 million notional interest rate swap | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | (474) | (297) | |
$476 million notional interest rate swap | Accounts payable and accrued liabilities | |||
Derivatives, Fair Value | |||
Fair value | (24) | (20) | |
$42 million notional interest rate swap | |||
Derivatives, Fair Value | |||
Fair value | (5) | (4) | |
$42 million notional interest rate swap | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | (3) | (3) | |
$42 million notional interest rate swap | Accounts payable and accrued liabilities | |||
Derivatives, Fair Value | |||
Fair value | (2) | (1) | |
Commodity contract derivatives | |||
Derivatives, Fair Value | |||
Fair value | (41) | 60 | |
Commodity contract derivatives | Other long-term assets | |||
Derivatives, Fair Value | |||
Fair value | 12 | 41 | |
Commodity contract derivatives | Other long-term liabilities | |||
Derivatives, Fair Value | |||
Fair value | (16) | (8) | |
Commodity contract derivatives | Other current assets | |||
Derivatives, Fair Value | |||
Fair value | 0 | 31 | |
Commodity contract derivatives | Accounts payable and accrued liabilities | |||
Derivatives, Fair Value | |||
Fair value | $ (37) | $ (4) | |
[1] | Letters of credit of approximately $1.3 billion and $921 million were posted as collateral at September 30, 2019 and 2018, respectively, to partially secure the liability positions of one of the currency swaps and one of the interest rate swaps in accordance with the collateral requirements for these derivatives. |
Risk Management Activities an_6
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Currency Swaps Outstanding (Details) £ in Millions | 12 Months Ended |
Sep. 30, 2019GBP (£)Bond_issues | |
Derivative | |
Number of British pound sterling denominated bond transactions | Bond_issues | 3 |
1999 Currency Swap Contract | |
Derivative | |
Effective Date of Currency Swap Contract | 1999 |
Associated TVA bond issues currency exposure | £ 200 |
Expiration Date of Swap | 2021 |
Overall effective cost to TVA | 5.81% |
2001 Currency Swap Contract | |
Derivative | |
Effective Date of Currency Swap Contract | 2001 |
Associated TVA bond issues currency exposure | £ 250 |
Expiration Date of Swap | 2032 |
Overall effective cost to TVA | 6.59% |
2003 Currency Swap Contract | |
Derivative | |
Effective Date of Currency Swap Contract | 2003 |
Associated TVA bond issues currency exposure | £ 150 |
Expiration Date of Swap | 2043 |
Overall effective cost to TVA | 4.96% |
Risk Management Activities an_7
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivatives Under Financial Trading Program (Details) - Natural Gas Contract Derivatives - USD ($) $ in Millions | 12 Months Ended | |
Sep. 30, 2019 | Sep. 30, 2018 | |
Derivative | ||
Decrease (increase) in fuel expense | $ 0 | $ (6) |
Decrease (increase) in purchased power expense | $ 0 | $ (2) |
Risk Management Activities an_8
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Counterparty Credit Risk (Details) $ in Millions | 12 Months Ended | |
Sep. 30, 2019USD ($)megawattsCustomers | Sep. 30, 2018USD ($) | |
Derivative | ||
Receivables from power sales | $ | $ 1,624 | $ 1,570 |
Credit of Customers | ||
Derivative | ||
Number of customers that represent the percent of sales | Customers | 2 | |
Percent of total sales by customers | 17.00% | |
Power Purchase Agreement | ||
Derivative | ||
Megawatts | megawatts | 440 |
Risk Management Activities an_9
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Offsetting of Derivative Assets (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | |
Offsetting Assets [Line Items] | |||
Commodity derivatives not subject to master netting or similar arrangement | [1] | $ 72 | |
Letter of Credit | |||
Offsetting Assets [Line Items] | |||
Amount of letters of credit outstanding | $ 1,300 | $ 900 | |
Other Contract | |||
Offsetting Assets [Line Items] | |||
Gross Amounts of Recognized Assets, subject to master netting or similar arrangements | 12 | ||
Net Amounts of Assets Presented in the Balance Sheet | [1] | $ 12 | |
[1] | There are no derivative contracts subject to a master netting arrangement or similar agreement that are not offset on the Consolidated Balance Sheets. |
Risk Management Activities a_10
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Offsetting of Derivative Liabilities (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | ||
Offsetting Liabilities [Line Items] | ||||
Gross Amounts of Recognized Liabilities, subject to master netting or similar arrangements | $ 1,972 | $ 1,293 | ||
Gross Amounts Offset in the Balance Sheet | [1] | 0 | 0 | |
Derivative Liability | [2] | 2,025 | 1,305 | |
Total derivatives not subject to master netting or similar arrangement | [2] | 53 | 12 | |
Total | 2,025 | 1,305 | ||
Currency Swap | ||||
Offsetting Liabilities [Line Items] | ||||
Gross Amounts of Recognized Liabilities, subject to master netting or similar arrangements | 208 | 94 | [3] | |
Gross Amounts Offset in the Balance Sheet | 0 | 0 | [1],[3] | |
Derivative Liability | [2],[3] | 208 | 94 | |
Interest Rate Contract | ||||
Offsetting Liabilities [Line Items] | ||||
Gross Amounts of Recognized Liabilities, subject to master netting or similar arrangements | 1,764 | 1,199 | [3] | |
Gross Amounts Offset in the Balance Sheet | 0 | 0 | [1],[3] | |
Derivative Liability | [2],[3] | 1,764 | 1,199 | |
Total derivatives subject to master netting or similar arrangement | ||||
Offsetting Liabilities [Line Items] | ||||
Derivative Liability | [2] | 1,972 | 1,293 | |
Letter of Credit | ||||
Offsetting Liabilities [Line Items] | ||||
Amount of letters of credit outstanding | $ 1,300 | $ 900 | ||
[1] | Amounts primarily include counterparty netting of derivative contracts, margin account deposits for futures commission merchants transactions, and cash collateral received or paid in accordance with the accounting guidance for derivatives and hedging transactions. | |||
[2] | There are no derivative contracts subject to a master netting arrangement or similar agreement that are not offset on the Consolidated Balance Sheets. | |||
[3] | Letters of credit of approximately $1.3 billion and $921 million were posted as collateral at September 30, 2019 and 2018, respectively, to partially secure the liability positions of one of the currency swaps and one of the interest rate swaps in accordance with the collateral requirements for these derivatives. |
Risk Management Activities a_11
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Other Derivative Instruments (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Derivative | ||
Forward Contract Derivative Asset, at Fair Value | $ 22 | $ 45 |
Fair Value, Inputs, Level 2 | ||
Derivative | ||
Forward Contract Derivative Asset, at Fair Value | $ 22 | $ 45 |
Risk Management Activities a_12
Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Collateral (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Derivative | ||
Likely collateral obligation increase if downgraded | $ 22 | |
Collateralized Securities [Member] | ||
Derivative | ||
Aggregate fair value of derivative instruments with credit-risk related contingent features that were in a liability position | 2,000 | |
Collateral obligations | 1,300 | |
Letter of Credit | ||
Derivative | ||
Amount of letters of credit outstanding | $ 1,300 | $ 900 |
Fair Value Measurements Fair _2
Fair Value Measurements Fair Value Measurements - Investments (Details) $ in Millions | 12 Months Ended | |
Sep. 30, 2019USD ($) | Sep. 30, 2018USD ($) | |
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Investment funds | $ 2,968 | $ 2,862 |
Balance in the NDT | 2,100 | |
Balance in the ART | $ 765 | |
Period of time where the investor contributes capital to an investment in a private partnership - minimum | three | |
Period of time where the investor contributes capital to an investment in a private partnership - maximum | four | |
Minimum investment period | 10 years | |
Fair value of gross plan assets | $ 8,472 | 8,531 |
Number of readily available quoted exchange prices for the investments | 0 | |
LTDCP | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Unrealized gains (losses) on investments | $ (2) | 1 |
SERP | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Unrealized gains (losses) on investments | 0 | 1 |
ART | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Unrealized gains (losses) on investments | (70) | 15 |
NDT | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Unrealized gains (losses) on investments | (112) | $ 18 |
Equity Funds [Member] | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Commitments, Fair Value Disclosure | 191 | |
Real Estate Funds [Member] | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Commitments, Fair Value Disclosure | 33 | |
Credit [Member] | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Commitments, Fair Value Disclosure | 22 | |
Private equity | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Commitments, Fair Value Disclosure | 96 | |
Private real estate funds | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Fair value of gross plan assets | 19 | |
Private Credit [Member] | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
Commitments, Fair Value Disclosure | 11 | |
Interest Payments relating to energy prepayment obligations | ||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings [Line Items] | ||
2019 | $ 4 |
Fair Value Measurements Fair _3
Fair Value Measurements Fair Value Measurements - Nonperformance Risk (Details) $ in Millions | Sep. 30, 2019USD ($) |
Nonperformance Risk | |
Derivative credit valuation adjustment, assets | $ 1 |
Derivative credit valuation adjustment, liabilities | $ 1 |
Fair Value Measurements Fair _4
Fair Value Measurements Fair Value Measurements - Fair Value Measurements (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | |||
Investments | |||||
Equity securities | $ 464 | $ 220 | |||
Government debt securities | 344 | 236 | |||
Corporate debt securities | 417 | 499 | |||
Mortgage and asset-backed securities | 32 | 50 | |||
Institutional mutual funds | 250 | 126 | |||
Forward debt securities contracts - asset | 22 | 45 | |||
Private equity funds measured at net asset value | 140 | [1] | 132 | ||
Private real estate measured at net asset value | 135 | [1] | 124 | ||
Private credit measured at net asset value | [1] | 33 | |||
Commingled funds measured at net asset value | 1,131 | [1] | 1,430 | ||
Total investments | 2,968 | 2,862 | |||
Commodity contract derivatives | 12 | 72 | |||
Total | 2,980 | 2,934 | |||
Liabilities | |||||
Currency swaps | 208 | [2] | 94 | [3] | |
Interest rate swaps | 1,764 | 1,199 | |||
Commodity contract derivatives | 53 | 12 | |||
Total | 2,025 | 1,305 | |||
Fair Value, Inputs, Level 1 | |||||
Investments | |||||
Equity securities | 464 | 220 | |||
Government debt securities | 279 | 199 | |||
Corporate debt securities | 0 | 0 | |||
Mortgage and asset-backed securities | 0 | 0 | |||
Institutional mutual funds | 250 | 126 | |||
Forward debt securities contracts - asset | 0 | 0 | |||
Private equity funds measured at net asset value | 0 | [1] | 0 | [4] | |
Private real estate measured at net asset value | 0 | [1] | 0 | [4] | |
Commingled funds measured at net asset value | 0 | [1] | 0 | [4] | |
Total investments | 993 | 545 | |||
Commodity contract derivatives | 0 | 0 | |||
Total | 993 | 545 | |||
Liabilities | |||||
Currency swaps | 0 | [2] | 0 | [3] | |
Interest rate swaps | 0 | 0 | |||
Commodity contract derivatives | 0 | 0 | |||
Total | 0 | 0 | |||
Fair Value, Inputs, Level 2 | |||||
Investments | |||||
Equity securities | 0 | 0 | |||
Government debt securities | 65 | 37 | |||
Corporate debt securities | 417 | 499 | |||
Mortgage and asset-backed securities | 32 | 50 | |||
Institutional mutual funds | 0 | 0 | |||
Forward debt securities contracts - asset | 22 | 45 | |||
Private equity funds measured at net asset value | 0 | [1] | 0 | [4] | |
Private real estate measured at net asset value | 0 | [1] | 0 | [4] | |
Commingled funds measured at net asset value | 0 | [1] | 0 | [4] | |
Total investments | 536 | 631 | |||
Commodity contract derivatives | 7 | 13 | |||
Total | 543 | 644 | |||
Liabilities | |||||
Currency swaps | 208 | [2] | 94 | [3] | |
Interest rate swaps | 1,764 | 1,199 | |||
Commodity contract derivatives | 44 | 11 | |||
Total | 2,016 | 1,304 | |||
Fair Value, Inputs, Level 3 | |||||
Investments | |||||
Equity securities | 0 | 0 | |||
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 | |||
Private equity funds measured at net asset value | 0 | [1] | 0 | [4] | |
Private real estate measured at net asset value | 0 | [1] | 0 | [4] | |
Commingled funds measured at net asset value | 0 | [1] | 0 | [4] | |
Total investments | 0 | 0 | |||
Commodity contract derivatives | 5 | 59 | |||
Total | 5 | 59 | |||
Liabilities | |||||
Currency swaps | 0 | [2] | 0 | [3] | |
Interest rate swaps | 0 | 0 | |||
Commodity contract derivatives | 9 | 1 | |||
Total | $ 9 | $ 1 | |||
[1] | Certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been categorized in the fair value hierarchy. 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. | ||||
[2] | 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 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities. | ||||
[3] | See Note 15 — Risk Management Activities and Derivative Transactions — Offsetting of Derivative Assets and Liabilities. | ||||
[4] | Certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been categorized in the fair value hierarchy. 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. |
Fair Value Measurements Fair _5
Fair Value Measurements Fair Value Measurements - Fair Value Measurements Using Significant Unobservable Inputs (Details) tons-per-year in Billions | 12 Months Ended | ||
Sep. 30, 2019USD ($)tons-per-year | Sep. 30, 2018USD ($)tons-per-year | Sep. 30, 2017USD ($) | |
Fair Value Measurements | |||
Commodity contract derivatives, assets | $ 12,000,000 | $ 72,000,000 | |
Commodity contract derivatives, liabilities | $ 53,000,000 | $ 12,000,000 | |
Minimum | |||
Assets | |||
Fair value measurements tons per year | tons-per-year | 0.4 | 0.7 | |
Price per ton | $ 12.10 | $ 12.25 | |
Liabilities | |||
Fair value measurements tons per year | tons-per-year | 0.4 | 0.7 | |
Price per ton | $ 12.10 | $ 12.25 | |
Maximum | |||
Assets | |||
Fair value measurements tons per year | tons-per-year | 0.8 | 0.8 | |
Price per ton | $ 94.51 | $ 112.24 | |
Liabilities | |||
Fair value measurements tons per year | tons-per-year | 0.8 | 0.8 | |
Price per ton | $ 94.51 | $ 112.24 | |
Commodity Contract Derivatives | |||
Fair Value Measurements | |||
Balance at beginning/end of period | (4,000,000) | 58,000,000 | $ (67,000,000) |
Change in net unrealized gains (losses) deferred as regulatory assets and liabilities | (62,000,000) | 125,000,000 | |
Fair Value, Inputs, Level 3 | |||
Fair Value Measurements | |||
Commodity contract derivatives, assets | 5,000,000 | 59,000,000 | |
Commodity contract derivatives, liabilities | $ 9,000,000 | $ 1,000,000 |
Fair Value Measurements Fair _6
Fair Value Measurements Fair Value Measurements - Estimated Values of Financial Instruments (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | Aug. 09, 2013 |
Estimated Values of Financial Instruments (Level 2 Valuation) | |||
EnergyRight receivables (including current portion) | $ 100 | $ 112 | |
Loans and other long-term receivables, net (including current portion) | 120 | 123 | |
EnergyRight® financing obligation (including current portion) | 126 | 143 | |
Unfunded Loan Commitments | 10 | 3 | |
Membership interests of VIE subject to mandatory redemption (including current portion) | 37 | 37 | $ 40 |
Long-term outstanding power bonds (including current maturities), net | 26,059 | 23,896 | |
Long-term debt of variable interest entities (including current maturities) | 1,371 | 1,256 | |
Long-term notes payable (including current maturities) | 23 | 68 | |
Secured debt of VIEs | |||
Estimated Values of Financial Instruments (Level 2 Valuation) | |||
EnergyRight receivables (including current portion) | 101 | 112 | |
Loans and other long-term receivables, net (including current portion) | 131 | 138 | |
EnergyRight® financing obligation (including current portion) | 113 | 127 | |
Unfunded Loan Commitments | 0 | 0 | |
Membership interests of VIE subject to mandatory redemption (including current portion) | 28 | 30 | |
Long-term outstanding power bonds (including current maturities), net | 20,124 | 21,189 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | 1,128 | ||
Long-term debt of variable interest entities (including current maturities) | 1,100 | 1,165 | |
Long-term notes payable (including current maturities) | $ 23 | $ 69 |
Proprietary Capital Proprieta_2
Proprietary Capital Proprietary Capital (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Appropriation Investment | |||||||||||
Amount of appropriation investment that was repaid | $ 1,000 | $ 1,000 | |||||||||
Remaining appropriation investment | 258 | 258 | |||||||||
Balance at beginning of year | $ 10,283 | $ 9,133 | 10,283 | $ 9,133 | $ 8,420 | ||||||
Net income (loss) | 588 | $ 165 | $ 241 | 423 | $ (101) | $ 470 | $ 462 | 288 | 1,417 | 1,119 | 685 |
Return on power program appropriation investment | (6) | (5) | (5) | ||||||||
Balance at end of year | 11,625 | 10,283 | 11,625 | 10,283 | $ 9,133 | ||||||
Net proprietary capital at September 30 | $ 11,625 | $ 10,283 | $ 11,625 | $ 10,283 | |||||||
Computed average interest rate payable | 2.37% | 2.09% | 2.37% | 2.09% | 2.00% | ||||||
Nonpower Programs Appropriation Investment | |||||||||||
Appropriation Investment | |||||||||||
Balance at beginning of year | 4,351 | $ 4,351 | |||||||||
Balance at end of year | $ 4,351 | $ 4,351 | 4,351 | $ 4,351 | |||||||
Power Program Appropriation Investment | |||||||||||
Appropriation Investment | |||||||||||
Balance at beginning of year | 258 | 258 | 258 | 258 | $ 258 | ||||||
Net income (loss) | 0 | 0 | 0 | ||||||||
Return on power program appropriation investment | 0 | 0 | 0 | ||||||||
Balance at end of year | 258 | 258 | 258 | 258 | 258 | ||||||
Power Program Retained Earnings | |||||||||||
Appropriation Investment | |||||||||||
Balance at beginning of year | 9,404 | 8,282 | 9,404 | 8,282 | 7,594 | ||||||
Net income (loss) | 1,425 | 1,127 | 693 | ||||||||
Return on power program appropriation investment | (6) | (5) | (5) | ||||||||
Balance at end of year | 10,823 | 9,404 | 10,823 | 9,404 | 8,282 | ||||||
Net proprietary capital at September 30 | 11,081 | 9,662 | 11,081 | 9,662 | |||||||
Nonpower Programs Appropriation Investment, Net | |||||||||||
Appropriation Investment | |||||||||||
Balance at beginning of year | 564 | 572 | 564 | 572 | 580 | ||||||
Net income (loss) | (8) | (8) | (8) | ||||||||
Return on power program appropriation investment | 0 | 0 | 0 | ||||||||
Balance at end of year | 556 | 564 | 556 | 564 | 572 | ||||||
Nonpower Programs Retained Earnings | |||||||||||
Appropriation Investment | |||||||||||
Balance at beginning of year | $ (3,787) | $ (3,779) | (3,787) | (3,779) | |||||||
Return on power program appropriation investment | 0 | 0 | |||||||||
Balance at end of year | (3,795) | (3,787) | (3,795) | (3,787) | (3,779) | ||||||
Net proprietary capital at September 30 | $ 556 | $ 564 | 556 | 564 | |||||||
Affiliated Entity | |||||||||||
Appropriation Investment | |||||||||||
Return on power program appropriation investment | $ (6) | $ (5) | $ (5) |
Proprietary Capital Proprieta_3
Proprietary Capital Proprietary Capital - Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||
Dec. 31, 2016 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Accumulated Other Comprehensive Income (Loss) | ||||
Net effect on earnings | $ 0 | $ 0 | ||
Net unrealized gain (loss) on future cash flow hedges | (114) | $ 10 | $ 59 | |
Reclassification to earnings from cash flow hedges | (45) | $ 26 | $ (26) | |
Reclassification to earnings from cash flow hedges in the next twelve months | $ (30) |
Other Income (Expense), Net O_2
Other Income (Expense), Net Other Income (Expense), Net (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Other Income (Expense), Net | |||
Change in other income (expense) | $ 12 | ||
Other income | $ 0 | $ 0 | |
Proceeds from Other Deposits | 21 | ||
Interest income | 25 | 23 | 23 |
External services | 13 | 14 | 14 |
Gain (Loss) on Investments | 3 | 6 | 9 |
Gains (losses) on investments | 2 | ||
Miscellaneous | 7 | 10 | |
Miscellaneous | 0 | ||
Total other income (expense), net | 62 | $ 50 | $ 56 |
Gain (Loss) on Disposition of Assets | $ 5 |
Supplemental Cash Flow Inform_2
Supplemental Cash Flow Information Supplemental Cash Flow Information (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||
Dec. 31, 2016 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Supplemental Cash Flow Information | ||||
Interest paid | $ 1,300 | $ 1,200 | $ 1,300 | |
Capital lease obligations incurred | 10 | |||
Power purchased under agreement | 10 | |||
Acquisition of notes payable | 74 | |||
Accounts payable and accrued liabilities | ||||
Supplemental Cash Flow Information | ||||
Construction in progress and Nuclear fuel expenditures | $ 324 | $ 372 | $ 425 |
Benefit Plans Components of Ben
Benefit Plans Components of Benefit Plans (Details) - USD ($) | 12 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2018 | |
Defined Benefit Plan Disclosure | |||
Fixed and variable fund annual maximum contribution | $ 10,000 | ||
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Assets Transferred to (from) Plan | 23,000,000 | ||
Defined contribution plan contribution amount | $ 88,000,000 | $ 84,000,000 | $ 80,000,000 |
Minimum | |||
Defined Benefit Plan Disclosure | |||
Threshold for Deferral of Actuarial Gain/Loss Under Corridor Approach | 10.00% |
Benefit Plans Obligations and F
Benefit Plans Obligations and Funded Status (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | ||
Change in benefit obligation | ||||
Actuarial loss (gain) | $ (3) | |||
Change in plan assets | ||||
Actual return on plan assets | $ 88 | |||
Amount related to experience loss | 59 | |||
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract] | ||||
Amount related to change in number of participants | 7 | |||
Amount related to change in payment elections | 46 | |||
Pension Benefits | ||||
Change in benefit obligation | ||||
Benefit obligation | 13,312 | 11,725 | ||
Defined Benefit Plan, Pension Plan with Projected Benefit Obligation in Excess of Plan Assets, Projected Benefit Obligation | 11,725 | 12,601 | ||
Service cost | 44 | 53 | $ 60 | |
Interest cost | 499 | 473 | $ 464 | |
Plan participants' contributions | 7 | 7 | ||
Change in Plan Assets due to Collections | [1] | 0 | 0 | |
Collections | [1] | 0 | 0 | |
Actuarial loss (gain) | 1,756 | (658) | ||
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment | 7 | 0 | ||
Net transfers from variable fund/401(k) plan | 1 | (26) | ||
Expenses paid | (6) | (6) | ||
Benefits paid | 721 | 719 | ||
Increase (Decrease) in Obligation, Other Postretirement Benefits | 110 | |||
Defined Benefit Plan, Pension Plan with Projected Benefit Obligation in Excess of Plan Assets, Plan Assets | 7,980 | 8,003 | ||
Change in plan assets | ||||
Fair value of net plan assets | 8,003 | 8,003 | ||
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets | 7,989 | |||
Actual return on plan assets | 389 | 454 | ||
Employer contributions | 307 | 304 | ||
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract] | ||||
Funded status | $ (5,332) | $ (3,722) | ||
Discount rate | 3.20% | 4.35% | 3.85% | |
Amount of defined benefit plan actuarial gain (loss) from discount rate change | $ (1,600) | $ (700) | ||
Amount of defined benefit plan actuarial gain (loss) from change in mortality assumption | (14) | (138) | ||
Other Post-retirement Benefits | ||||
Change in benefit obligation | ||||
Benefit obligation | 499 | 428 | ||
Postconfirmation, Other Postretirement Obligations | 428 | 494 | ||
Service cost | 11 | 14 | $ 18 | |
Interest cost | 18 | 19 | $ 21 | |
Plan participants' contributions | 0 | 0 | ||
Change in Plan Assets due to Collections | [1] | 22 | 25 | |
Collections | [1] | 22 | 25 | |
Actuarial loss (gain) | 78 | (46) | ||
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | (17) | ||
Net transfers from variable fund/401(k) plan | 0 | 0 | ||
Expenses paid | 0 | 0 | ||
Benefits paid | 58 | 61 | ||
Increase (Decrease) in Obligation, Other Postretirement Benefits | 17 | |||
Change in plan assets | ||||
Fair value of net plan assets | 0 | 0 | ||
Actual return on plan assets | 0 | 0 | ||
Employer contributions | 36 | 36 | ||
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract] | ||||
Funded status | $ (499) | $ (428) | ||
Discount rate | 3.30% | 4.40% | ||
Amount of defined benefit plan actuarial gain (loss) from updated capita claims costs and retiree contributions | $ (24) | $ (8) | ||
Amount of change related to actual | 7 | 23 | ||
Amount of defined benefit plan actuarial gain (loss) from discount rate change | $ (71) | (28) | ||
Amount of defined benefit plan actuarial gain (loss) from change in mortality assumption | $ (6) | |||
Defined Benefit Plan, Assumptions Used in Calculation, Description | 0.033 | 0.044 | 0.0395 | |
Amount of defined benefit plan actuarial gain (loss) from change in health care trend rate assumptions | $ 24 | |||
[1] | Collections include retiree contributions as well as provider discounts and rebates. |
Benefit Plans Amounts Recognize
Benefit Plans Amounts Recognized on TVA's Consolidated Balance Sheets (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | |
Defined Benefit Plan Disclosure | |||
Regulatory assets | $ 8,763 | $ 6,612 | |
Non-current regulatory liabilities | 0 | (104) | |
Accounts payable and accrued liabilities | (1,812) | (1,982) | |
Pension and post-retirement benefit obligations | (6,181) | (4,476) | |
Pension Benefits | |||
Defined Benefit Plan Disclosure | |||
Amount capitalized due to actions of regulator | 95 | 96 | |
Regulatory assets | 4,731 | 3,119 | |
Accounts payable and accrued liabilities | (5) | (6) | |
Pension and post-retirement benefit obligations | [1] | (5,327) | (3,716) |
Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Amount capitalized due to actions of regulator | 0 | 0 | |
Regulatory assets | 73 | ||
Non-current regulatory liabilities | (25) | ||
Accounts payable and accrued liabilities | (28) | (28) | |
Pension and post-retirement benefit obligations | [1] | (471) | (400) |
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent | |||
Defined Benefit Plan Disclosure | |||
Postemployment benefits liability, noncurrent | $ 383 | $ 360 | |
[1] | The table above excludes $383 million and $360 million of post-employment benefit costs that are recorded in Post-retirement and post-employment benefit obligations on the Consolidated Balance Sheets at September 30, 2019 and 2018, respectively. |
Benefit Plans Postretirement Be
Benefit Plans Postretirement Benefit Costs Deferred as Regulatory Assets (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Defined Benefit Plan Disclosure | ||
Regulatory assets | $ (8,763) | $ (6,612) |
Non-current regulatory liabilities | 0 | 104 |
Pension Benefits | ||
Defined Benefit Plan Disclosure | ||
Unrecognized prior service cost (credit) | (714) | (819) |
Unrecognized net loss | 5,350 | 3,842 |
Amount capitalized due to actions of regulator | (95) | (96) |
Regulatory assets | (4,731) | (3,119) |
Other Post-retirement Benefits | ||
Defined Benefit Plan Disclosure | ||
Unrecognized prior service cost (credit) | (135) | (159) |
Unrecognized net loss | 160 | 86 |
Amount capitalized due to actions of regulator | 0 | 0 |
Regulatory assets | $ (73) | |
Non-current regulatory liabilities | $ 25 |
Benefit Plans Projected Benefit
Benefit Plans Projected Benefit Obligations and Accumulated Benefit Obligations in Exess of Plan Assets (Details) - Pension Benefits - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Defined Benefit Plan Disclosure | ||
Projected benefit obligation | $ 11,725 | |
Accumulated benefit obligation | $ 13,246 | 11,659 |
Defined Benefit Plan, Pension Plan with Projected Benefit Obligation in Excess of Plan Assets, Plan Assets | 7,980 | 8,003 |
Fair value of net plan assets | $ 8,003 | $ 8,003 |
Benefit Plans Components of Net
Benefit Plans Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Pension Benefits | ||||
Defined Benefit Plan Disclosure | ||||
Service cost | $ 44 | $ 53 | $ 60 | |
Interest cost | 499 | 473 | 464 | |
Expected return on plan assets | 477 | 478 | 457 | |
Amortization of prior service credit | (99) | (99) | (99) | |
Recognized net actuarial loss | (336) | (409) | (472) | |
Net periodic benefit cost as acutarially determined | 303 | 358 | 440 | |
Amount expensed (capitalized) due to actions of regulator | (1) | 54 | (365) | |
Total net period benefit cost | 304 | 304 | 805 | |
Other Post-retirement Benefits | ||||
Defined Benefit Plan Disclosure | ||||
Service cost | 11 | 14 | 18 | |
Interest cost | 18 | 19 | 21 | |
Expected return on plan assets | 0 | 0 | 0 | |
Amortization of prior service credit | (24) | (22) | (22) | |
Recognized net actuarial loss | (4) | 8 | 14 | |
Net periodic benefit cost as acutarially determined | 9 | 19 | 31 | |
Amount expensed (capitalized) due to actions of regulator | 0 | 0 | 0 | |
Total net period benefit cost | $ 9 | $ 19 | $ 31 | |
Scenario, Forecast | Pension Benefits | ||||
Defined Benefit Plan Disclosure | ||||
Amount expensed (capitalized) due to actions of regulator | $ (13) |
Benefit Plans Expected Amortiza
Benefit Plans Expected Amortization of Regulatory Assets in Next Fiscal Year (Details) $ in Millions | 12 Months Ended |
Sep. 30, 2019USD ($) | |
Defined Benefit Plan Disclosure | |
Prior service cost (credit) | $ (121) |
Net actuarial loss | 444 |
Pension Benefits | |
Defined Benefit Plan Disclosure | |
Prior service cost (credit) | (97) |
Net actuarial loss | 435 |
Other Post-retirement Benefits | |
Defined Benefit Plan Disclosure | |
Prior service cost (credit) | (24) |
Net actuarial loss | $ 9 |
Benefit Plans Actuarial Assumpt
Benefit Plans Actuarial Assumptions (Details) - USD ($) | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Defined Benefit Plan Disclosure | |||
Period during which actual company compensation experience study performed | 5 years | ||
Defined Benefit Plan, Cost of Living Adjustment Assumption | 25.00% | ||
Pension Benefits | |||
Defined Benefit Plan Disclosure | |||
Discount rate | 4.35% | 3.85% | 3.65% |
Discount rate | 3.20% | 4.35% | 3.85% |
Rate of compensation increase | 4.00% | 3.60% | |
Expected return on plan assets | 7.00% | 6.75% | 7.00% |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Increase (Decrease) for Plan Amendment | $ 6.7500 | ||
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 | 3.50% | 5.34% | 5.43% |
COLA percentage increase (decrease) | 600.00% | ||
Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Discount rate | 4.40% | 3.95% | 3.70% |
Discount rate | 3.30% | 4.40% | |
Defined Benefit Plan, Cost of Living Adjustment Assumption | 2.00% | 2.00% | 2.00% |
Minimum | |||
Defined Benefit Plan Disclosure | |||
Rate of compensation increase | 2.50% | ||
Maximum | |||
Defined Benefit Plan Disclosure | |||
Rate of compensation increase | 14.00% | ||
Pre-Medicare Eligible [Member] | Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Initial health care cost trend rate | 6.25% | 6.50% | 6.50% |
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 | 2027 | 2024 | |
Initial health care cost trend rate | $ 0.0675 | $ 0.0625 | |
Post-Medicare Eligible [Member] [Member] | Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Initial health care cost trend rate | 0.00% | 0.00% | 0.00% |
Ultimate health care cost trend rate | 4.00% | 4.00% | 4.00% |
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate | 2023 | 2021 |
Benefit Plans Sensitivity to Ce
Benefit Plans Sensitivity to Certain Changes in Pension Assumptions (Details) - USD ($) | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Defined Benefit Plan Disclosure | |||
Defined Benefit Plan, Cost of Living Adjustment Assumption | 25.00% | ||
Discount rate | |||
Defined Benefit Plan Disclosure | |||
Change in Assumption | (0.25%) | ||
Impact on Pension Cost | $ 16,000,000 | ||
Impact on Projected Benefit Obligation | $ 399,000,000 | ||
Rate of return on plan assets | |||
Defined Benefit Plan Disclosure | |||
Change in Assumption | (0.25%) | ||
Impact on Pension Cost | $ 14,000,000 | ||
Cost of Living Adjustments [Domain] | |||
Defined Benefit Plan Disclosure | |||
Change in Assumption | 0.25% | ||
Impact on Pension Cost | $ 27,000,000 | ||
Impact on Projected Benefit Obligation | $ 261,000,000 | ||
Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Defined Benefit Plan, Cost of Living Adjustment Assumption | 2.00% | 2.00% | 2.00% |
Discount rate | 3.30% | 4.40% | |
Actuarial assumption COLA | $ 0.0221 | $ 1.8400 | $ 0.9900 |
Pension Benefits | |||
Defined Benefit Plan Disclosure | |||
Defined Benefit Plan, Cost of Living Adjustment Assumption | 2.00% | 2.00% | 2.00% |
COLA percentage increase (decrease) | 600.00% | ||
Discount rate | 3.20% | 4.35% | 3.85% |
Pre-Medicare Eligible [Member] | Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate | 5.00% | 5.00% | 5.00% |
Benefit Plans Sensitivity to Ch
Benefit Plans Sensitivity to Changes in Assumed Health Care Cost Trend Rates (Details) $ in Millions | 12 Months Ended |
Sep. 30, 2019USD ($) | |
Maximum | |
Defined Benefit Plan Disclosure | |
Effect of one percentage point increase on total service and interest cost components | $ 4 |
Effect of one percentage point increase on end-of-year accumulated postretirement benefit obligation | 71 |
Minimum | |
Defined Benefit Plan Disclosure | |
Effect of one percentage point decrease on total service and interest cost components | (4) |
Effect of one percentage point decrease on end-of-year accumulated postretirement benefit obligation | $ (68) |
Benefit Plans Asset Holdings (D
Benefit Plans Asset Holdings (Details) - USD ($) | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Defined Benefit Plan Disclosure | |||
Target Allocation | 100.00% | ||
Plan Asset Allocations | 100.00% | 100.00% | |
Global public equity | |||
Defined Benefit Plan Disclosure | |||
Target Allocation | 35.00% | ||
Plan Asset Allocations | 37.00% | 44.00% | |
Public real assets | |||
Defined Benefit Plan Disclosure | |||
Target Allocation | 15.00% | ||
Plan Asset Allocations | 15.00% | 15.00% | |
Private equity | |||
Defined Benefit Plan Disclosure | |||
Target Allocation | 8.00% | ||
Plan Asset Allocations | 10.00% | 7.00% | |
Safety oriented fixed income | |||
Defined Benefit Plan Disclosure | |||
Target Allocation | 17.00% | ||
Plan Asset Allocations | 18.00% | 16.00% | |
Opportunistic fixed income | |||
Defined Benefit Plan Disclosure | |||
Target Allocation | 15.00% | ||
Plan Asset Allocations | 12.00% | 10.00% | |
Private real assets | |||
Defined Benefit Plan Disclosure | |||
Target Allocation | 10.00% | ||
Plan Asset Allocations | 8.00% | 8.00% | |
Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Actuarial assumption COLA | $ 0.0221 | $ 1.8400 | $ 0.9900 |
Benefit Plans Fair Value Measur
Benefit Plans Fair Value Measurements (Details) $ in Millions | 12 Months Ended | |||
Sep. 30, 2019USD ($)Years | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | ||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | $ 8,472 | $ 8,531 | ||
Estimated future decommissioning cost | [1] | 5,616 | 4,779 | $ 4,304 |
Derivative liabilities | 136 | 115 | ||
Net payables | 132 | 95 | ||
Payables for collateral on loaned securities | $ 224 | 318 | ||
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 | $ 2,670 | 2,644 | ||
Derivative liabilities | 4 | 3 | ||
Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 2,800 | 2,774 | ||
Derivative liabilities | 132 | 112 | ||
Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 58 | 88 | ||
Estimated future decommissioning cost | 42 | 58 | ||
Derivative liabilities | 0 | 0 | ||
Equity securities | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1,766 | 1,787 | ||
Equity securities | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1,762 | 1,786 | ||
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 | 4 | 1 | ||
Preferred securities | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 10 | 10 | ||
Preferred securities | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | 4 | ||
Preferred securities | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 9 | 6 | ||
Preferred securities | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Corporate debt securities | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1,387 | 1,151 | ||
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 | 1,382 | 1,148 | ||
Corporate debt securities | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 5 | 3 | ||
Residential mortgage-backed securities | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 427 | 377 | ||
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 | 424 | 371 | ||
Residential mortgage-backed securities | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 3 | 6 | ||
Debt securities issued by U.S. Treasury and other U.S. government agencies | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 807 | 696 | ||
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 | 807 | 696 | ||
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 | ||
Asset-backed securities | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 144 | 129 | ||
Asset-backed securities | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Asset-backed securities | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 116 | 103 | ||
Asset-backed securities | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 28 | 26 | ||
Debt securities issued by state/local governments | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 18 | 17 | ||
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 | 18 | 17 | ||
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 | 210 | 322 | ||
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 | 209 | 304 | ||
Debt securities issued by foreign governments | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | 18 | ||
Commercial mortgage-backed securities | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 81 | 74 | ||
Commercial mortgage-backed securities | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Commercial mortgage-backed securities | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 80 | 70 | ||
Commercial mortgage-backed securities | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | 4 | ||
Equity security commingled funds | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 795 | 1,175 | ||
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 | 308 | 317 | ||
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 | ||
Commodity commingled funds | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 217 | 232 | ||
Commodity commingled funds | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Commodity commingled funds | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Commodity commingled funds | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Blended security commingled funds | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 125 | 109 | ||
Blended security commingled funds | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Blended security commingled funds | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Blended 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 | 97 | 109 | ||
Institutional mutual funds | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 97 | 109 | ||
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 | 329 | 466 | ||
Cash equivalents and other short-term investments | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | 42 | ||
Cash equivalents and other short-term investments | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 328 | 424 | ||
Cash equivalents and other short-term investments | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Certificates of deposit | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 3 | 2 | ||
Certificates of deposit | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Certificates of deposit | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 3 | 2 | ||
Certificates of deposit | 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 | 78 | 8 | ||
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 | 891 | 631 | ||
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 | 546 | 583 | ||
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 | 224 | 318 | ||
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 | 224 | 318 | ||
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 | ||||
Fair value of gross plan assets | 2 | 7 | ||
Derivative liabilities | 4 | 3 | ||
Futures | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 2 | 7 | ||
Derivative liabilities | 4 | 3 | ||
Futures | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Derivative liabilities | 0 | 0 | ||
Futures | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Derivative liabilities | 0 | 0 | ||
Purchased options | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 5 | |||
Purchased options | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | |||
Purchased options | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 5 | |||
Purchased options | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | |||
Interest Rate Swap | ||||
Defined Benefit Plan Disclosure | ||||
Derivative liabilities | 12 | |||
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 | 12 | |||
Interest Rate Swap | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Derivative liabilities | 0 | |||
Foreign currency forward | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | 3 | ||
Derivative liabilities | 1 | 3 | ||
Foreign currency forward | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Derivative liabilities | 0 | 0 | ||
Foreign currency forward | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | 3 | ||
Derivative liabilities | 1 | 3 | ||
Foreign currency forward | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | 0 | ||
Derivative liabilities | 0 | 0 | ||
Written options | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 8 | |||
Written options | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | |||
Written options | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 8 | |||
Written options | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | |||
Credit default swaps | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | |||
Derivative liabilities | 1 | 1 | ||
Credit default swaps | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | |||
Derivative liabilities | 0 | 0 | ||
Credit default swaps | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 1 | |||
Derivative liabilities | 1 | 1 | ||
Credit default swaps | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Fair value of gross plan assets | 0 | |||
Derivative liabilities | 0 | 0 | ||
Securities Sold under Agreements to Repurchase [Member] | ||||
Defined Benefit Plan Disclosure | ||||
Derivative liabilities | 118 | 108 | ||
Securities Sold under Agreements to Repurchase [Member] | Fair Value, Inputs, Level 1 | ||||
Defined Benefit Plan Disclosure | ||||
Derivative liabilities | 0 | 0 | ||
Securities Sold under Agreements to Repurchase [Member] | Fair Value, Inputs, Level 2 | ||||
Defined Benefit Plan Disclosure | ||||
Derivative liabilities | 118 | 108 | ||
Securities Sold under Agreements to Repurchase [Member] | Fair Value, Inputs, Level 3 | ||||
Defined Benefit Plan Disclosure | ||||
Derivative liabilities | $ 0 | $ 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 | 12 | |||
Number of one year extensions for partnerships in private equity | Years | 3 | |||
[1] | (1) The current portions of the ARO liability in the amounts of $163 million and $115 million at September 30, 2019 and 2018, respectively, are included in Accounts payable and accrued liabilities. |
Benefit Plans Fair Value Meas_2
Benefit Plans Fair Value Measurements Using Significant Unobservable Inputs (Details) - USD ($) $ in Millions | 12 Months Ended | |
Sep. 30, 2019 | Sep. 30, 2018 | |
Defined Benefit Plan Disclosure | ||
Net payables | $ 132 | $ 95 |
Payables for collateral on loaned securities | 224 | 318 |
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation [Roll Forward] | ||
Fair value of gross plan assets | 8,472 | 8,531 |
Net realized/unrealized gains | 88 | |
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 | 58 | 88 |
Net realized/unrealized gains | 4 | (4) |
Purchases, sales, issuances, and settlements, net | (12) | (23) |
Transfers in and/or out of Level 3 | (8) | $ (3) |
Fair value of net plan assets | $ 42 |
Benefit Plans Estimated Future
Benefit Plans Estimated Future Benefit Payments (Details) $ in Millions | Sep. 30, 2019USD ($) |
Pension Benefits | |
Defined Benefit Plan Disclosure | |
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months | $ 782 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Two | 779 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Three | 778 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Four | 775 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Five | 771 |
Defined Benefit Plan, Expected Future Benefit Payment, Five Fiscal Years Thereafter | 3,786 |
Other Post-retirement Benefits | |
Defined Benefit Plan Disclosure | |
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months | 29 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Two | 27 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Three | 25 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Four | 24 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Five | 22 |
Defined Benefit Plan, Expected Future Benefit Payment, Five Fiscal Years Thereafter | $ 111 |
Benefit Plans Contributions (De
Benefit Plans Contributions (Details) - USD ($) | 12 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2018 | |
Defined Benefit Plan Disclosure | |||
Defined contribution plan contribution amount | $ 88,000,000 | $ 84,000,000 | $ 80,000,000 |
Other postretirement benefit contributions | 36,000,000 | 25,000,000 | |
Contribution related to TVARS case | 4,000,000 | 15,000,000 | |
Expected Payment for Postretirement Benefits | 29,000,000 | ||
Supplemental Employee Retirement Plans, Defined Benefit | |||
Defined Benefit Plan Disclosure | |||
Defined Benefit Plan, Expected Payments Related to SERP | 5,000,000 | ||
Defined Benefit Plan, Related to SERP | 7,000,000 | 4,000,000 | |
Other Post-retirement Benefits | |||
Defined Benefit Plan Disclosure | |||
Employer contributions | 36,000,000 | 36,000,000 | |
Pension Benefits | |||
Defined Benefit Plan Disclosure | |||
Employer contributions | 307,000,000 | $ 304,000,000 | |
Other Pension Plans, Defined Benefit | |||
Defined Benefit Plan Disclosure | |||
Employer contributions | 300,000,000 | ||
Minimum | Other Pension Plans, Defined Benefit | |||
Defined Benefit Plan Disclosure | |||
Employer contributions | $ 300,000,000 | ||
Scenario, Forecast | Other Pension Plans, Defined Benefit | |||
Defined Benefit Plan Disclosure | |||
Employer contributions | $ 300,000,000 |
Benefit Plans Other Postemploym
Benefit Plans Other Postemployment Benefits (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Other Post-Employment Benefits | |||
Discount rate | 1.68% | 3.05% | 2.33% |
Period expense | $ 59 | $ 6 | |
Postemployment benefits liability | 419 | 339 | |
Accounts Payable and Accrued Liabilities | |||
Other Post-Employment Benefits | |||
Postemployment Benefits Liability, Current | 36 | 39 | |
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent | |||
Other Post-Employment Benefits | |||
Postemployment benefits liability, noncurrent | $ 383 | $ 360 |
Commitments and Contingencies_2
Commitments and Contingencies Commitments and Contingencies - Table (Details) $ in Millions | Sep. 30, 2019USD ($)megawatts | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | |
Obligations | ||||
Megawatts provided under transmission obligations | megawatts | 1,450 | |||
Accrual for Environmental Loss Contingencies, Gross | $ 15 | $ 12 | ||
Estimated future decommissioning cost | [1] | 5,616 | 4,779 | $ 4,304 |
2018 | 53 | |||
2019 | 53 | |||
2020 | 53 | |||
2021 | 55 | |||
2022 | 51 | |||
Thereafter | 418 | |||
Total | 683 | |||
2018 | 76 | |||
2019 | 75 | |||
2020 | 60 | |||
2021 | 12 | |||
2022 | 3 | |||
Thereafter | 2 | |||
Total | 228 | |||
CT and QTE outstanding leaseback obligation | 263 | $ 301 | ||
2018 | 50 | |||
2019 | 207 | |||
2020 | 25 | |||
2021 | 0 | |||
2022 | 0 | |||
Thereafter | 0 | |||
Total | $ 282 | |||
[1] | (1) The current portions of the ARO liability in the amounts of $163 million and $115 million at September 30, 2019 and 2018, respectively, are included in Accounts payable and accrued liabilities. |
Commitments and Contingencies_3
Commitments and Contingencies Commitments and Contingencies - Energy Prepayment Obligations (Details) $ in Millions | Sep. 30, 2019USD ($) |
Interest Payments relating to energy prepayment obligations | |
Obligations | |
2019 | $ 4 |
Commitments and Contingencies_4
Commitments and Contingencies Commitments and Contingencies - Membership Interests of VIE Subject to Mandatory Redemption (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 | Aug. 09, 2013 |
Long-term Purchase Commitment | |||
Membership interests of VIE subject to mandatory redemption (including current portion) | $ 37 | $ 37 | $ 40 |
2018 | 3 | ||
Total | 282 | ||
2019 | 3 | ||
2020 | 3 | ||
2021 | 2 | ||
2022 | $ 1 |
Commitments and Contingencies_5
Commitments and Contingencies Commitments and Contingencies - Leases (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Leases | |||
Operating lease expense | $ 97 | $ 92 | $ 90 |
2018 | 50 | ||
CT and QTE outstanding leaseback obligation | 263 | $ 301 | |
2018 | 53 | ||
2018 | 76 | ||
2019 | 75 | ||
2020 | 60 | ||
2021 | 12 | ||
2022 | 3 | ||
Thereafter | 2 | ||
Total | 228 | ||
2019 | 53 | ||
2020 | 53 | ||
2021 | 55 | ||
2022 | 51 | ||
Thereafter | 418 | ||
Total | 683 | ||
Less: amount representing interest | (495) | ||
Total | 188 | ||
2019 | 207 | ||
2020 | 25 | ||
2021 | 0 | ||
2022 | 0 | ||
Thereafter | 0 | ||
Total | $ 282 |
Commitments and Contingencies_6
Commitments and Contingencies Commitments and Contingencies - Purchase Obligations (Details) $ in Millions | 12 Months Ended | ||
Sep. 30, 2019USD ($)megawattsMegawatts | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | |
Obligations | |||
Megawatts provided under power purchase obligations | 2,230 | ||
Remaining terms of the agreements, high end of range | 13 years | ||
Megawatts provided under transmission obligations | megawatts | 1,450 | ||
Power purchased under agreement | $ | $ 195 | $ 188 | $ 178 |
Maximum term length for the purchase, storage, and transportation of natural gas | four | ||
Purchase Agreements Required by Federal Law | |||
Obligations | |||
Megawatts provided under power purchase obligations | 263 |
Commitments and Contingencies_7
Commitments and Contingencies Commitments and Contingencies - Contingencies (Details) $ in Millions | 12 Months Ended | |||
Sep. 30, 2019USD ($)UnitsInsurance_layersProceduresreactors | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | ||
Contingencies | ||||
Loss Contingency, Damages Sought, Value | $ 30 | |||
Nuclear liability insurance | 450 | |||
Assessment from licensees for each licensed reactor | $ 138 | |||
Number of licensed reactors in US | reactors | 98 | |||
Nuclear accident assessment limitation per year per unit | $ 20 | |||
Number of licensed nuclear units | Units | 7 | |||
Maximum assessment per nuclear incident | $ 963 | |||
Total amount of protection available | $ 14,000 | |||
Number of layers until the U.S. Congress is required to take action | Insurance_layers | 2 | |||
Amount of insurance available for loss at any one site | $ 2,100 | |||
Maximum amount of retrospective premiums | 139 | |||
Maximum idemnity if a covered accident tasks or keeps a nuclear unit offline | 490 | |||
Maximum amount of retrospective premiums | 46 | |||
Estimated future decommissioning cost | [1] | $ 5,616 | $ 4,779 | $ 4,304 |
Number of procedures for determining estimates for the costs of nuclear decommissioning | Procedures | 2 | |||
Amount spent to reduce emissions since 1970 | $ 6,800 | |||
Amount spent to reduce emissions | 17 | 62 | 206 | |
Possible additional future costs for compliance with Clean Air Act requirements | 142 | |||
Possible additional future costs for compliance with CCR requirements | 1,181 | |||
Possible additional future costs for compliance with Clean Water requirements. | 278 | |||
Estimated liability for cleanup and similar environmental work on a non-discounted basis | 15 | 12 | ||
Nuclear | ||||
Contingencies | ||||
Estimated future decommissioning cost | 3,136 | 2,989 | 2,859 | |
Non-nuclear | ||||
Contingencies | ||||
Estimated future decommissioning cost | $ 2,480 | $ 1,790 | $ 1,445 | |
[1] | (1) The current portions of the ARO liability in the amounts of $163 million and $115 million at September 30, 2019 and 2018, respectively, are included in Accounts payable and accrued liabilities. |
Commitments and Contingencies_8
Commitments and Contingencies Commitments and Contingencies - Legal Proceedings (Details) $ in Millions | 12 Months Ended | |
Sep. 30, 2019USD ($)megawattsUnitsGroupsAgreements | Sep. 30, 2018USD ($) | |
Legal Proceedings | ||
Possible additional future costs for compliance with CCR requirements | $ 1,181 | |
Amount spent under environmental agreements | 279 | |
Contribution related to TVARS case | 4 | $ 15 |
Possible additional future costs for compliance with Clean Water requirements. | 278 | |
Amount to Pay Consent Decree | 0 | |
General | ||
Legal Proceedings | ||
Legal loss contingency accrual | $ 14 | |
Environmental Agreements | ||
Legal Proceedings | ||
Number of similar environmental agreements entered into | Agreements | 2 | |
Number of environmental agreements entered into with the EPA | Agreements | 1 | |
Number of environmental agreements entered into with environmental advocacy groups | Groups | 3 | |
Number of units to be idled | Units | 18 | |
Megawatts option 1 | megawatts | 2,200 | |
Megawatts option 2 | 3,500 | |
Amount to be invested in certain environmental projects | $ 290 | |
Amount to be provided to fund environmental projects | 60 | |
Amount to pay civil penalties | 10 | |
Other long-term liabilities | General | ||
Legal Proceedings | ||
Legal loss contingency accrual | 12 | |
Accounts payable and accrued liabilities | General | ||
Legal Proceedings | ||
Legal loss contingency accrual | $ 2 |
Commitments and Contingencies U
Commitments and Contingencies Unfunded loan commitments (Details) $ in Millions | Sep. 30, 2019USD ($) |
Legal Proceedings | |
2018 | $ 7 |
Energy prepayment obligations | |
Legal Proceedings | |
Prepayment Obligations | $ 10 |
Related Parties Related Parti_2
Related Parties Related Parties (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Related Parties | |||||||||||
Remaining appropriation investment | $ 258 | $ 258 | |||||||||
Current borrowing capacity | 150 | 150 | |||||||||
Revenue from sales of electricity | 3,239 | $ 2,604 | $ 2,750 | $ 2,725 | $ 3,185 | $ 2,707 | $ 2,792 | $ 2,549 | 11,318 | $ 11,233 | $ 10,739 |
Other income | 0 | 0 | |||||||||
Return on power program appropriation investment | (6) | (5) | (5) | ||||||||
Related Party Transactions | |||||||||||
Related Parties | |||||||||||
Revenue from sales of electricity | 118 | 122 | 126 | ||||||||
Other income | 258 | 240 | 136 | ||||||||
Operating expenses | 222 | 220 | 216 | ||||||||
Additions to property, plant, and equipment | 10 | 8 | 16 | ||||||||
Cash and cash equivalents | 45 | 46 | 45 | 46 | 46 | ||||||
Accounts receivable, net | 76 | 60 | 76 | 60 | 84 | ||||||
Receivables, Long-term Contracts or Programs | 53 | 46 | 53 | 46 | 35 | ||||||
Accounts payable and accrued liabilities | 69 | 69 | 69 | 69 | 71 | ||||||
Long-term power bonds, net | $ 0 | $ 0 | 0 | 0 | 1 | ||||||
Return on power program appropriation investment | $ (6) | $ (5) | $ (5) |
Unaudited Quarterly Financial_3
Unaudited Quarterly Financial Information Unaudited Quarterly Financial Information (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Quarterly Financial Information Disclosure [Abstract] | |||||||||||
Revenue from sales of electricity | $ 3,239 | $ 2,604 | $ 2,750 | $ 2,725 | $ 3,185 | $ 2,707 | $ 2,792 | $ 2,549 | $ 11,318 | $ 11,233 | $ 10,739 |
Operating expenses | 2,301 | 2,088 | 2,158 | 1,960 | 2,745 | 1,942 | 2,027 | 1,951 | 8,507 | 8,665 | 8,006 |
Operating income | 938 | 516 | 592 | 765 | 440 | 765 | 765 | 598 | 2,811 | 2,568 | 2,733 |
Net income (loss) | $ 588 | $ 165 | $ 241 | $ 423 | $ (101) | $ 470 | $ 462 | $ 288 | $ 1,417 | $ 1,119 | $ 685 |
Gallatin coal combustion residu
Gallatin coal combustion residual facilities (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Sep. 30, 2018 |
Other long-term liabilities | ||
Other Long-Term Liabilities | ||
Gallatin coal combustion residual facilities | $ 0 | $ 862 |
Revenue (Details)
Revenue (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | |
Revenue Recognition and Deferred Revenue [Abstract] | |||||||||||
Sales of Electricity (subtotal) | $ 11,155 | $ 11,079 | $ 10,602 | ||||||||
Electric revenue | (11,159) | (11,075) | (10,586) | ||||||||
Off-system sales | 4 | 7 | 6 | ||||||||
Other revenue | 159 | 158 | 153 | ||||||||
Revenue from sales of electricity | $ 3,239 | $ 2,604 | $ 2,750 | $ 2,725 | $ 3,185 | $ 2,707 | $ 2,792 | $ 2,549 | $ 11,318 | $ 11,233 | $ 10,739 |
Revenue Revenue (Details)
Revenue Revenue (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||||||||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2004 | |
Electric revenue | $ 11,159 | $ 11,075 | $ 10,586 | |||||||||
Percentage of total operating revenues [Abstract] | ||||||||||||
Other revenue | 159 | 158 | 153 | |||||||||
Revenues | $ 3,239 | $ 2,604 | $ 2,750 | $ 2,725 | $ 3,185 | $ 2,707 | $ 2,792 | $ 2,549 | $ 11,318 | $ 11,233 | 10,739 | |
MLGW's % of operating revenues | 9.00% | |||||||||||
NES's % of operating revenues | 8.00% | |||||||||||
MLGW prepayment | $ 1,500 | |||||||||||
MLGW | ||||||||||||
Percentage of total operating revenues [Abstract] | ||||||||||||
Deferred Revenue, Description | 10 | 100 | 100 | |||||||||
Federal agencies and other [Member] | ||||||||||||
Electric revenue | $ 122 | $ 129 | 132 | |||||||||
20-year contract arrangement [Member] | ||||||||||||
Electric revenue | 6,350 | |||||||||||
10-year contract arrangement [Member] | ||||||||||||
Electric revenue | 938 | |||||||||||
5-year contract arrangement [Member] | ||||||||||||
Electric revenue | 3,063 | |||||||||||
Local Power Company [Member] | ||||||||||||
Electric revenue | 10,351 | 10,262 | 9,741 | |||||||||
Industries Directly Served [Member] | ||||||||||||
Electric revenue | 686 | 695 | 735 | |||||||||
Capitalized revenue during pre-commercial plant operations [Member] | ||||||||||||
Electric revenue | $ 0 | $ 11 | $ 22 |
Revenue Energy Prepayment Oblig
Revenue Energy Prepayment Obligations (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2004 | |
Energy Prepayment Obligation [Line Items] | ||||
Electric revenue | $ 11,159 | $ 11,075 | $ 10,586 | |
Energy Prepayment Discount | $ 4 | $ 46 | ||
MLGW | ||||
Energy Prepayment Obligation [Line Items] | ||||
Deferred Revenue, Description | 10 | 100 | 100 |
Revenue Economic Development In
Revenue Economic Development Incentives (Details) - USD ($) $ in Millions | 12 Months Ended | |
Sep. 30, 2019 | Sep. 30, 2018 | |
Revenue from Contract with Customer [Abstract] | ||
Revenues | $ 310 | $ 276 |
Unpaid economic incentives | $ 157 | $ 145 |
Subsequent Events Subsequent _3
Subsequent Events Subsequent Events (Details) $ in Millions | 12 Months Ended |
Sep. 30, 2019USD ($) | |
Debt Instrument, Redemption [Line Items] | |
Amount of bonds redeemed | $ 217 |
Plant Closures (Details)
Plant Closures (Details) $ in Millions | 12 Months Ended |
Sep. 30, 2019USD ($) | |
Property, Plant and Equipment [Abstract] | |
Write-offs related to retirement of plants | $ 151 |
Write-offs materials and supplies | 19 |
Accelerated depreciation | $ 566 |