10-K 1 tve-10xk09302019.htm 10-K

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(MARK ONE)
x ANNUAL REPORT PURSUANT TO
SECTION 13, 15(d), OR 37 OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended September 30, 2019
OR
o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _____ to _____
Commission file number 000-52313
TENNESSEE VALLEY AUTHORITY
(Exact name of registrant as specified in its charter)

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

(865) 632-2101
(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:

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

Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Yes o No x
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
Yes o No x
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13, 15(d), or 37 of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yes x No o
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Yes x No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large accelerated filer o Accelerated filer o
Non-accelerated filer x Smaller reporting company o
Emerging growth company o
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yes o No x

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Table of Contents
GLOSSARY OF COMMON ACRONYMS....................................................................................................................................................................................................... | 4
FORWARD-LOOKING INFORMATION......................................................................................................................................................................................................... | 6
GENERAL INFORMATION............................................................................................................................................................................................................................ | 7
PART I |
ITEM 1. BUSINESS...................................................................................................................................................................................................................................... | 8
The Corporation................................................................................................................................................................................................................................. | 8
Service Area....................................................................................................................................................................................................................................... | 9
Customers.......................................................................................................................................................................................................................................... | 10
Rates.................................................................................................................................................................................................................................................. | 11
Power Supply and Load Management Resources............................................................................................................................................................................. | 11
Fuel Supply......................................................................................................................................................................................................................................... | 16
Transmission...................................................................................................................................................................................................................................... | 19
Weather and Seasonality.................................................................................................................................................................................................................... | 19
Competition........................................................................................................................................................................................................................................ | 20
Research and Development............................................................................................................................................................................................................... | 20
Flood Control Activities....................................................................................................................................................................................................................... | 21
Environmental Stewardship Activities................................................................................................................................................................................................. | 21
Economic Development Activities...................................................................................................................................................................................................... | 21
Regulation.......................................................................................................................................................................................................................................... | 22
Taxation and Tax Equivalents............................................................................................................................................................................................................. | 23
Environmental Matters....................................................................................................................................................................................................................... | 23
Employees.......................................................................................................................................................................................................................................... | 29
ITEM 1A. RISK FACTORS............................................................................................................................................................................................................................ | 29
ITEM 1B. UNRESOLVED STAFF COMMENTS............................................................................................................................................................................................ | 42
ITEM 2. PROPERTIES.................................................................................................................................................................................................................................. | 42
Generating Properties........................................................................................................................................................................................................................ | 42
Transmission Properties..................................................................................................................................................................................................................... | 44
Natural Resource Stewardship Properties......................................................................................................................................................................................... | 44
Buildings............................................................................................................................................................................................................................................. | 44
Disposal of Property........................................................................................................................................................................................................................... | 44
ITEM 3. LEGAL PROCEEDINGS.................................................................................................................................................................................................................. | 45
ITEM 4. MINE SAFETY DISCLOSURES...................................................................................................................................................................................................... | 45
PART II |
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES............ | 46
ITEM 6. SELECTED FINANCIAL DATA........................................................................................................................................................................................................ | 46
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS................................................................... | 47
Business and Mission......................................................................................................................................................................................................................... | 47
Executive Overview............................................................................................................................................................................................................................ | 49
Results of Operations......................................................................................................................................................................................................................... | 50
Liquidity and Capital Resources......................................................................................................................................................................................................... | 58
Off-Balance Sheet Arrangements....................................................................................................................................................................................................... | 63
Key Initiatives and Challenges........................................................................................................................................................................................................... | 63
Critical Accounting Policies and Estimates......................................................................................................................................................................................... | 70
Fair Value Measurements................................................................................................................................................................................................................... | 75
New Accounting Standards and Interpretations................................................................................................................................................................................. | 76
Legislative and Regulatory Matters.................................................................................................................................................................................................... | 76
Environmental Matters....................................................................................................................................................................................................................... | 77
Legal Proceedings.............................................................................................................................................................................................................................. | 77
Risk Management Activities............................................................................................................................................................................................................... | 77
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK........................................................................................................................... | 79
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.......................................................................................................................................................... | 80
Consolidated Balance Sheets............................................................................................................................................................................................................ | 81
Consolidated Statements of Operations............................................................................................................................................................................................. | 80
Consolidated Statements of Comprehensive Income (Loss)............................................................................................................................................................. | 83
Consolidated Statements of Cash Flows........................................................................................................................................................................................... | 84

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Consolidated Statements of Changes in Proprietary Capital............................................................................................................................................................. | 85
Notes to Consolidated Financial Statements..................................................................................................................................................................................... | 86
Report of Independent Registered Public Accounting Firm............................................................................................................................................................... | 148
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE............................................................... | 149
ITEM 9A. CONTROLS AND PROCEDURES............................................................................................................................................................................................... | 149
Disclosure Controls and Procedures.................................................................................................................................................................................................. | 149
Internal Control over Financial Reporting........................................................................................................................................................................................... | 149
Report of Independent Registered Public Accounting Firm................................................................................................................................................................ | 150
ITEM 9B. OTHER INFORMATION................................................................................................................................................................................................................ | 151
PART III |
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE............................................................................................................................. | 152
Directors.............................................................................................................................................................................................................................................. | 152
Executive Officers............................................................................................................................................................................................................................... | 153
Disclosure and Financial Code of Ethics............................................................................................................................................................................................ | 155
Committees of the TVA Board............................................................................................................................................................................................................ | 155
ITEM 11. EXECUTIVE COMPENSATION..................................................................................................................................................................................................... | 155
Compensation Discussion and Analysis............................................................................................................................................................................................. | 155
Executive Compensation Tables and Narrative Disclosures.............................................................................................................................................................. | 169
Retirement and Pension Plans........................................................................................................................................................................................................... | 173
Nonqualified Deferred Compensation................................................................................................................................................................................................ | 176
Potential Payments on Account of Retirement/Resignation, Termination without Cause, Termination with Cause, Death, or Disability........................................... | 177
Other Agreements.............................................................................................................................................................................................................................. | 182
CEO Pay Ratio Disclosure................................................................................................................................................................................................................. | 182
Director Compensation....................................................................................................................................................................................................................... | 183
Compensation Committee Interlocks and Insider Participation.......................................................................................................................................................... | 185
Compensation Committee Report...................................................................................................................................................................................................... | 185
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS...................................... | 185
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE......................................................................................... | 185
Director Independence....................................................................................................................................................................................................................... | 185
Related Party Transactions................................................................................................................................................................................................................ | 185
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES...................................................................................................................................................................... | 187
PART IV |
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES..................................................................................................................................................................... | 188
ITEM 16. FORM 10-K SUMMARY................................................................................................................................................................................................................. | 191
SIGNATURES................................................................................................................................................................................................................................................ | 192

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GLOSSARY OF COMMON ACRONYMS
Following are definitions of some of the terms or acronyms that may be used in this Annual Report on Form 10-K for the fiscal year ended September 30, 2019 (the "Annual Report"):
Term or Acronym |  | Definition
AOCI |  | Accumulated other comprehensive income (loss)
ARO |  | Asset retirement obligation
ART |  | Asset Retirement Trust
BLEU |  | Blended low-enriched uranium
Bonds |  | Bonds, notes, or other evidences of indebtedness
CAA |  | Clean Air Act
CCR |  | Coal combustion residuals
CERCLA |  | Comprehensive Environmental Response, Compensation, and Liability Act
CME |  | Chicago Mercantile Exchange
CO 2 |  | Carbon dioxide
COLA |  | Cost-of-living adjustment
CSAPR |  | Cross-State Air Pollution Rule
CTs |  | Combustion turbine unit(s)
CVA |  | Credit valuation adjustment
CY |  | Calendar year
DCP |  | Deferred Compensation Plan
DER |  | Distributed Energy Resources
DOE |  | Department of Energy
EIS |  | Environmental Impact Statement
ELGs |  | Effluent Limitation Guidelines
EPA |  | Environmental Protection Agency
EPRI |  | Electric Power Research Institute
ESPA |  | Early Site Permit Application
FASB |  | Financial Accounting Standards Board
FERC |  | Federal Energy Regulatory Commission
FPA |  | Federal Power Act
FTP |  | Financial Trading Program
GAAP |  | Accounting principles generally accepted in the United States of America
GHG |  | Greenhouse gas
IRP |  | Integrated Resource Plan
JSCCG |  | John Sevier Combined Cycle Generation LLC
kW |  | Kilowatts
kWh |  | Kilowatt hours
LPC |  | Local power company customers
LTDCP |  | Long-Term Deferred Compensation Plan
MATS |  | Mercury and Air Toxics Standards
MD&A |  | Management's Discussion and Analysis of Financial Condition and Results of Operations
MLGW |  | Memphis Light, Gas and Water Division
mmBtu |  | Million British thermal unit(s)
MtM |  | Mark-to-market
MW |  | Megawatts
NAAQS |  | National Ambient Air Quality Standards
NAV |  | Net asset value
NDT |  | Nuclear Decommissioning Trust
NEIL |  | Nuclear Electric Insurance Limited
NEPA |  | National Environmental Policy Act

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NERC |  | North American Electric Reliability Corporation
NES |  | Nashville Electric Service
NO 2 |  | Nitrogen dioxide
NO x |  | Nitrogen oxides
NPDES |  | National Pollutant Discharge Elimination System
NRC |  | Nuclear Regulatory Commission
NSR |  | New Source Review
NYSE |  | New York Stock Exchange
OCI |  | Other comprehensive income (loss)
OMB |  | Office of Management and Budget
PARRS |  | Putable Automatic Rate Reset Securities
PM |  | Particulate matter
QTE |  | Qualified technological equipment and software
RECs |  | Renewable Energy Certificates
REIT |  | Real Estate Investment Trust
RSO |  | Renewable Standard Offer
SCCG |  | Southaven Combined Cycle Generation LLC
SCRs |  | Selective catalytic reduction systems
SEC |  | Securities and Exchange Commission
SERP |  | Supplemental Executive Retirement Plan
SHLLC |  | Southaven Holdco LLC
SMR |  | Small modular reactor(s)
SO 2 |  | Sulfur dioxide
SOA |  | Society of Actuaries
SSSL |  | Seven States Southaven, LLC
TCWN |  | Tennessee Clean Water Network
TDEC |  | Tennessee Department of Environment & Conservation
TIPS |  | Treasury Inflation-Protected Securities
TVA Act |  | The Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee
TVARS |  | Tennessee Valley Authority Retirement System
U.S. Treasury |  | United States Department of the Treasury
USACE |  | U.S. Army Corps of Engineers
VIE |  | Variable interest entity

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FORWARD-LOOKING INFORMATION
This Annual Report on Form 10-K ("Annual Report") contains forward-looking statements relating to future events and future performance. All statements other than those that are purely historical may be forward-looking statements. In certain cases, forward-looking statements can be identified by the use of words such as "may," "will," "should," "expect," "anticipate," "believe," "intend," "project," "plan," "predict," "assume," "forecast," "estimate," "objective," "possible," "probably," "likely," "potential," "speculate," the negative of such words, or other similar expressions.
Although the Tennessee Valley Authority ("TVA") believes that the assumptions underlying any forward-looking statements are reasonable, TVA does not guarantee the accuracy of these statements. Numerous factors could cause actual results to differ materially from those in any forward-looking statements. These factors include, among other things:

• | New, amended, or existing laws, regulations, or administrative orders or interpretations, including those related to environmental matters, and the costs of complying with these laws, regulations, or administrative orders or interpretations;

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

• | Significant reductions in demand for electricity produced through non-renewable or centrally located generation sources that may result from, among other things, economic downturns, increased energy efficiency and conservation, increased utilization of distributed generation and microgrids, and improvements in alternative generation and energy storage technologies;

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

• | Changes in technology;

• | Actions taken, or inaction, by the U.S. government relating to the national or TVA debt ceiling or automatic spending cuts in government programs;

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

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

• | Significant delays, cost increases, or cost overruns associated with the construction and maintenance of generation, transmission, navigation, flood control, or related assets;

• | Requirements or decisions changing the amount or timing of funding obligations associated with TVA's pension plans, other post-retirement benefit plans, or health care plans;

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

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

• | Physical attacks on TVA's assets;

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

• | The outcome of legal or administrative proceedings;

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

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

• | Weather conditions;

• | Catastrophic events such as fires, earthquakes, explosions, solar events, electromagnetic pulses ("EMP"), geomagnetic disturbances ("GMDs"), droughts, floods, hurricanes, tornadoes, or other casualty events or pandemics, wars, national emergencies, terrorist activities, or other similar events, especially if these events occur in or near TVA's service area;

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

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

• | Disruption of fuel supplies, which may result from, among other things, economic conditions, weather conditions, production or transportation difficulties, labor challenges, or environmental laws or regulations affecting TVA's fuel suppliers or transporters;

• | Purchased power price volatility and disruption of purchased power supplies;

• | Events which affect the supply of water for TVA's generation facilities;

• | Changes in TVA's determinations of the appropriate mix of generation assets;

• | Ineffectiveness of TVA's efforts at adapting its organization to an evolving marketplace and remaining cost competitive;

• | Inability to obtain, or loss of, regulatory approval for the construction or operation of assets;

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

6

• | Limitations on TVA's ability to borrow money which may result from, among other things, TVA's approaching or substantially reaching the limit on bonds, notes, and other evidences of indebtedness specified in the Tennessee Valley Authority Act of 1933 (the "TVA Act");

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

• | Changes in the economy and volatility in financial markets;

• | Reliability or creditworthiness of counterparties;

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

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

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

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

• | Inability to eliminate identified deficiencies in TVA's systems, standards, controls, or corporate culture;

• | Inability to attract or retain a skilled workforce;

• | Inability to respond quickly enough to current or potential customer demands or needs;

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

• | Loss of quorum of the TVA Board of Directors (the "TVA Board");

• | Changes in the priorities of the TVA Board or TVA senior management; or

• | Other unforeseeable events.

See also Item 1A, Risk Factors, and Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations. New factors emerge from time to time, and it is not possible for management to predict all such factors or to assess the extent to which any factor, or combination of factors, may impact TVA's business or cause results to differ materially from those contained in any forward-looking statement. TVA undertakes no obligation to update any forward-looking statement to reflect developments that occur after the statement is made.
GENERAL INFORMATION
Fiscal Year
References to years (2019, 2018, etc.) in this Annual Report are to TVA's fiscal years ending September 30 except for references to years in the biographical information about directors and executive officers in Item 10, Directors, Executive Officers and Corporate Governance, as well as to years that are preceded by "CY," which references are to calendar years.
Notes
References to "Notes" are to the Notes to Consolidated Financial Statements contained in Item 8, Financial Statements and Supplementary Data in this Annual Report.
Property
TVA does not own real property and real property interests (collectively, "real property"). TVA acquires real property in the name of the United States, and such legal title in real property is entrusted to TVA as the agent of the United States to accomplish the purposes of the TVA Act. TVA acquires personal property in the name of TVA. Accordingly, unless the context indicates the reference is to TVA's personal property, any statement in this Annual Report referring to TVA property shall be read as referring to the real property of the United States that has been entrusted to TVA as its agent.
Available Information
TVA files annual, quarterly, and current reports with the Securities and Exchange Commission ("SEC") under Section 37 of the Securities Exchange Act of 1934. TVA's SEC filings are available to the public on the SEC's website at www.sec.gov or on TVA's website at www.tva.gov. Information contained on TVA's website shall not be deemed to be incorporated into, or to be a part of, this Annual Report.
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PART I
ITEM 1. BUSINESS
The Corporation
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 United States, and sell the electricity generated at the facilities TVA operates. Today, TVA operates the nation's largest public power system and supplies power to a population of nearly 10 million people.
TVA 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. TVA also manages the river system to provide recreational opportunities, adequate water supply, improved water quality, natural resource protection, and economic development. TVA performs these management duties in cooperation with other federal and state agencies that have jurisdiction and authority over certain aspects of the river system. In addition, the TVA Board of Directors (the "TVA Board") has established two councils — the Regional Resource Stewardship Council and the Regional Energy Resource Council — to advise TVA on its stewardship activities in the Tennessee Valley and its energy resource activities.
Initially, all TVA operations were funded by federal appropriations. Direct appropriations for the TVA power program ended in 1959, and appropriations for TVA's stewardship, economic development, and multipurpose activities ended in 1999. Since 1999, TVA has funded all of its operations almost entirely from the sale of electricity and power system financings. TVA's power system financings consist primarily of the sale of bonds, notes, or other evidences of indebtedness (collectively, "Bonds") and secondarily of alternative forms of financing, such as lease arrangements. As a wholly-owned government corporation, TVA is not authorized to issue equity securities.
8

Service Area
TVA's service area, the area in which it sells power, is defined by the TVA Act. TVA 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. Under the TVA Act, subject to certain minor exceptions, TVA may not, without the enactment of authorizing federal legislation, enter into contracts that would have the effect of making it, or the wholesale customers that distribute TVA power ("local power company customers" or "LPCs"), a source of power supply outside the area for which TVA or its LPCs were the primary source of power supply on July 1, 1957. This provision is referred to as the "fence" because it bounds TVA's sales activities, essentially limiting TVA to power sales within a defined service area.
Note
See Power Supply and Load Management Resources.
In addition, the Federal Power Act ("FPA") includes a provision that helps protect TVA's ability to sell power within its service area. This provision, called the "anti-cherrypicking" provision, prevents the Federal Energy Regulatory Commission ("FERC") from ordering TVA to provide access to its transmission lines to others to deliver power to customers within TVA's defined service area. As a result, the anti-cherrypicking provision reduces TVA's exposure to loss of its customers.
In 2019, the revenues generated from TVA's electricity sales were $11.2 billion and accounted for virtually all of TVA's revenues. See Note 17 — Revenue for details regarding revenues by state for each of the last three years.
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Customers
TVA is primarily a wholesaler of power, selling power to LPCs that then resell power to their customers at retail rates. TVA's LPCs consist of (1) municipalities and other local government entities ("municipalities") and (2) customer-owned entities ("cooperatives"). These municipalities and cooperatives operate public power electric systems whose primary purpose is not to make a profit but to supply electricity to the general public or the cooperatives' members. TVA also sells power directly to certain end-use customers, primarily large commercial and industrial loads and federal agencies with loads larger than 5,000 kilowatts ("kW"). Whether TVA or an LPC serves a new power customer is determined by the applicable TVA-LPC wholesale power contract. Each contract contains a formula that balances the size of the LPC and the amount of any TVA infrastructure investment to determine which party is entitled to serve the new customer. In addition, power in excess of the needs of the TVA system may, where consistent with the provisions of the Tennessee Valley Authority Act of 1933 (the "TVA Act"), be sold under exchange power arrangements with other specific electric systems. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations — Financial Results — Operating Revenues. See Note 17 — Revenue for details regarding operating revenues for each of the last three years.
Local Power Companies
Revenues from LPCs accounted for approximately 91 percent of TVA's total operating revenues in 2019. At September 30, 2019, TVA had wholesale power contracts with 154 LPCs. Each of these contracts requires the LPC to purchase from TVA all of the electric power required for service to the LPC's customers. LPCs purchase power under contracts with terms that range from five to 20 years to terminate.
TVA's two largest LPCs — Memphis Light, Gas and Water Division ("MLGW") and Nashville Electric Service ("NES") — have contracts with a five-year and a 20-year termination notice period, respectively. Sales to MLGW and NES accounted for nine percent and eight percent, respectively, of TVA's total operating revenues in 2019.
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. 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, which represents 56 percent of total operating revenues in 2019.
The power contracts between TVA and LPCs provide for the purchase of power by LPCs at the wholesale rates established by the TVA Board. Under the TVA Act, the TVA Board is authorized to regulate LPCs to carry out the purposes of the TVA Act through contract terms and conditions as well as through rules and regulations. TVA regulates LPCs primarily through the provisions of TVA's wholesale power contracts. All of the power contracts between TVA and the LPCs require that power purchased from TVA be sold and distributed to the ultimate consumer without discrimination among consumers of the same class and prohibit direct or indirect discriminatory rates, rebates, or other special concessions. In addition, there are a number of wholesale power contract provisions through which TVA seeks to ensure that the electric system revenues of the LPCs are used only for electric system purposes. Furthermore, almost all of these contracts specify the resale rates and charges at which the LPC must resell TVA power to its customers. These rates are revised from time to time, subject to TVA approval, to reflect changes in costs, including changes in the wholesale cost of power.
TVA also regulates LPC policies for customer deposits, termination of service for non-payment, information to consumers, and billing through a service practice policy framework. TVA's regulatory framework provides for consistent regulatory policy for ratepayers across the Tennessee Valley, while recognizing local considerations. The regulatory provisions in TVA's wholesale power contracts are designed to carry out the objectives of the TVA Act, including the objective of providing for adequate supply of power at the lowest feasible rates. See Rates — Rate Methodology below.
Other Customers
Revenues from directly served industrial customers accounted for approximately six percent of TVA's total operating revenues in 2019. Contracts with these customers are subject to termination by the customer or TVA upon a minimum notice period that varies according to a number of factors, including the customer's contract demand and the period of time service has been provided. TVA also serves seven federal customers, ‎including U.S. Department of Energy ("DOE") facilities and military installations, which accounted for approximately one percent of TVA's total operating revenues in 2019.
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 minor items. Other revenue accounted for approximately two percent of TVA's total operating revenues in 2019.
10

Rates
Rate Authority
The TVA Act gives the TVA Board sole responsibility for establishing the rates TVA charges for power. These rates are not subject to judicial review or to review or approval by any state or federal regulatory body. Under the TVA Act, TVA is required 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 government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment"); and

• | Such additional margin as the TVA Board may consider desirable for investment in power system assets, retirement of outstanding bonds, notes, or other evidences of indebtedness (collectively, "Bonds") in advance of their maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected with TVA's power business, having 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. See Note 18 — Proprietary Capital.

TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment in 2014; therefore, the repayment of this amount is no longer a component of rate setting.
Rate Methodology
TVA uses a seasonal time of use wholesale rate structure comprised of base demand and energy rates, a fuel rate, and a grid access charge ("GAC"). In setting the base rates, TVA uses a debt-service coverage ("DSC") methodology to derive annual revenue requirements in a manner similar to that used by other public power entities that also use the DSC rate methodology. Under the DSC methodology, rates are calculated so that an entity will be able to cover its operating costs and to satisfy its obligations to pay principal and interest on debt. This ratemaking approach is particularly suitable for use by entities financed primarily, if not entirely, by debt, such as TVA, and helps ensure that TVA produces gross revenues sufficient to fund requirements specified in the TVA Act listed under Rate Authority above.
TVA recovers fuel costs and tax equivalent payments associated with fuel cost adjustments through a monthly rate reflecting the forecasted costs of fuel. Beginning on October 1, 2018, fuel costs are allocated to three groups of customers: Standard Service (residential and small commercial customers), Large Manufacturing customers with contract demands greater than 5 megawatts ("MW"), and Large General Service customers with contract demands greater than 5 MW. Fuel costs are allocated to these three classes of customers in relation to their hourly loads and TVA's hourly incremental dispatch cost. Total monthly fuel costs include costs for natural gas, fuel oil, coal, purchased power, emission allowances, nuclear fuel, and other fuel-related commodities as well as realized gains and losses on derivatives purchased to hedge the costs of such commodities.
In recent years, TVA, LPCs, and directly served industries have worked collaboratively to develop changes to TVA's rate structures that focus on TVA's long-term pricing efforts. These changes are improving pricing by better aligning rates with underlying cost drivers and by sending improved pricing signals, while maintaining competitive industrial rates and keeping residential rates affordable. The rate structures are also designed to reduce wholesale energy rates for Standard Service and introduce a GAC at an offsetting rate to better recover fixed costs. This approach will more accurately reflect the wholesale cost of energy and recognize the value of the grid's reliability and associated fixed costs. TVA's modernized approach to pricing provides bill stability while maintaining reliability and fairness for all TVA's customers.
Power Supply and Load Management Resources
General
TVA seeks to balance production capabilities with power supply requirements by promoting the conservation and efficient use of electricity and, when necessary, buying, building, or leasing assets or entering into power purchase agreements. TVA also seeks to employ a diverse mix of energy generating sources and works toward obtaining greater amounts of its power supply from clean (low or zero carbon emitting) resources.
Power generating facilities operated by TVA at September 30, 2019, included three nuclear sites, 17 natural gas and/or oil-fired sites, six coal-fired sites, 29 conventional hydroelectric sites, one pumped-storage hydroelectric site, one diesel generator site, and 14 solar energy sites, although certain of these facilities were out of service as of September 30, 2019. See Item 2, Properties — Generating Properties — Net Capability for a discussion of these facilities. TVA also acquires power under power purchase agreements of varying durations, including short-term contracts of less than 24-hours in duration. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations — Financial Results — Operating Expenses.
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The following table shows TVA's generation and purchased power by generating source as a percentage of all
electric power generated and purchased (based on kilowatt hours ("kWh")) for the periods indicated:

Power Supply by Generating Source For the years ended September 30
Generation Resource(1) |  | 2019 |  | 2018 |  | 2017
Nuclear |  | 39% |  | 39% |  | 38%
Natural gas and/or oil-fired |  | 20% |  | 20% |  | 16%
Coal-fired |  | 17% |  | 19% |  | 25%
Hydroelectric |  | 10% |  | 9% |  | 7%
Purchased power (non-renewable) |  | 9% |  | 9% |  | 9%
Purchased power (renewable) |  | 5% |  | 4% |  | 5%

Note
(1) TVA's non-hydro renewable resources from TVA facilities are less than one percent for all periods shown, and therefore are not represented on the table above. Purchased power (renewable) contains the majority of non-hydro renewable energy supply.
Nuclear
At September 30, 2019, TVA had three nuclear sites consisting of seven units in operation. The units at Browns Ferry Nuclear Plant ("Browns Ferry") are boiling water reactor units, and the units at Sequoyah Nuclear Plant ("Sequoyah") and Watts Bar Nuclear Plant ("Watts Bar") are pressurized water reactor units. Operating information for each of these units is included in the table below.

TVA Nuclear Power At September 30, 2019
Nuclear Unit |  | Summer Net Capability (MW) |  | Net Capacity Factor for 2019 (%) |  | Date of Expiration of Operating License
Browns Ferry Unit 1(1) |  | 1,101 |  | 94.3 |  | 2033
Browns Ferry Unit 2(1) |  | 1,103 |  | 84.3 |  | 2034
Browns Ferry Unit 3(1) |  | 1,105 |  | 101.7 |  | 2036
Sequoyah Unit 1 |  | 1,152 |  | 93.3 |  | 2040
Sequoyah Unit 2 |  | 1,140 |  | 86.3 |  | 2041
Watts Bar Unit 1 |  | 1,157 |  | 80.9 |  | 2035
Watts Bar Unit 2 |  | 1,164 |  | 84.3 |  | 2055

Note
(1) The summer net capability for Browns Ferry excludes the impact of the Extended Power Uprate project. The generating capability is expected to increase by an estimated 465 MW after sufficient run time to validate the new capacity.
Extended Power Uprate. On August 14, 2017, the Nuclear Regulatory Commission ("NRC") approved TVA's request for a 465 MW extended power uprate ("EPU") project at Browns Ferry. As of September 30, 2019, physical work on all units was complete and the generation capacity is expected to increase 465 MW after sufficient run time to validate the new capacity. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Generation Resources — Extended Power Uprate.
Other Nuclear Initiatives. TVA has submitted an Early Site Permit Application to the NRC to license small modular reactors ("SMRs") at TVA's Clinch River Site in Oak Ridge, Tennessee. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Generation Resources — Small Modular Reactors.
Other Nuclear Matters. Operating nuclear facilities subjects TVA to waste disposal, decommissioning, and insurance requirements, as well as litigation risks. See Fuel Supply — Nuclear Fuel below for a discussion of spent nuclear fuel and low-level radioactive waste, Note 22 — Commitments and Contingencies — Contingencies for a discussion of TVA's nuclear decommissioning liabilities and the related trust and nuclear insurance, and Note 22 — Commitments and Contingencies — Legal Proceedings for a discussion of legal and administrative proceedings related to TVA's nuclear program, which discussions are incorporated herein by reference.
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Natural Gas and/or Oil-Fired
As of September 30, 2019, TVA's natural gas and oil-fired fleet consisted of 101 combustion turbine power blocks (86 simple-cycle units and 14 combined-cycle power units). Sixty of the simple-cycle units are currently capable of quick-start response allowing full generation capability in approximately 10 minutes. The economic dispatch of natural gas-fired plants depends on both the day-to-day price of natural gas and the price of other available intermediate resources such as coal-fired plants. TVA uses simple-cycle units to meet peaking or backup power needs. TVA also uses cogeneration at one simple-cycle unit. TVA's 2019 Integrated Resource Plan ("IRP") projects significant solar expansion over the next decade. The natural gas-fired fleet supports that expansion by providing reliability across all hours, as well as the flexibility to help manage ramping and intermittency.
See Item 2, Properties — Generating Properties, Note 9, Note 10, and Note 13 for a discussion of lease arrangements into which TVA has entered in connection with certain combustion turbine units. Because of TVA's strategy of portfolio diversification and reduction of air emissions, TVA may decide to make further strategic investments in natural gas-fired facilities in the future by purchase, construction, or lease.
Coal-Fired
As of September 30, 2019, TVA had six coal-fired plants consisting of 26 active units, accounting for 7,886 MW of summer net capability. TVA considers units to be in an active state when the unit is generating, available for service, or temporarily unavailable due to equipment failures, inspections, or repairs. All other coal-fired units are considered retired. 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"). 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 Paradise would not be restarted after January 2020 due to the plant's material condition.
Coal-fired plants have been subject to increasingly stringent regulatory requirements over the last few decades, including those under the Clean Air Act ("CAA"), the Environmental Protection Agency's ("EPA") Coal Combustion Residuals ("CCR") Rule, and the associated regulations. TVA has committed to a programmatic approach for the evaluation of its sites where CCR is stored to meet all applicable state and federal regulations. Increasing regulatory costs have caused TVA to consider whether to make the required capital investments to continue operating its coal-fired facilities. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Generation Resources — Coal Combustion Residual Facilities.
TVA is moving toward a more balanced generation plan with greater reliance on lower-cost and cleaner energy generation technologies. Since September 30, 2010, TVA has reduced its summer net capability of coal-fired units by 6,682 MW. The 2019 IRP indicated evaluation of additional coal unit retirements. Most of the remaining coal-fired plants are among the oldest in the nation still in operation, and their fit within TVA's power supply portfolio will be further tested in the future with increasing amounts of solar generation utilized by TVA. TVA's long-range plans will continue to consider the costs and benefits of significant environmental and other major capital investments at its remaining coal-fired plants.
Hydroelectric
Conventional Hydroelectric Dams. TVA maintains 29 conventional hydroelectric dams with 113 generating units throughout the Tennessee River system for the production of electricity. As of September 30, 2019, these units accounted for 3,784 MW of summer net capability. The amount of electricity that TVA is able to generate from its hydroelectric plants depends on a number of factors, including the amount of precipitation and runoff, initial water levels, generating unit availability, and the need for water for competing water management objectives. When these factors are unfavorable, TVA must increase its reliance on higher cost generation plants and purchased power. In addition, a portion of energy generated by nine U.S. Army Corps of Engineers ("USACE") dams on the Cumberland River system contributes to the TVA power system. See Weather and Seasonality below and Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Dam Safety and Remediation Initiatives.
Raccoon Mountain Pumped-Storage Plant. As of September 30, 2019, TVA has four units at Raccoon Mountain Pumped-Storage Plant ("Raccoon Mountain") with a total net summer capability of 1,616 MW. These units are utilized to balance the transmission system as well as generate power. TVA uses electricity generated by its fleet during periods of low demand to operate pumps that fill the reservoir at Raccoon Mountain. Then, during periods of high or peak demand, the water is released and the pumps reverse to work as power generating turbines.
Hiwassee Hydro Unit 2. Hiwassee Hydro Unit 2 has a unique reversible turbine/generator that acts as a pump and a turbine enhancing TVA's ability to balance baseload generation. Hiwassee Hydro Unit 2 has a summer net capability of 86 MW.
Hydro Modernization Program. TVA is scheduled to complete the Hydro Modernization Program in 2020 with the completion of South Holston Unit 1 and Pickwick Landing Dam ("Pickwick") Unit 2. The Hydro Modernization Program began in
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1992 and focuses on units with potential to increase peaking capacity and improve reliability. As of September 30, 2019, modernization had been completed on 61 conventional hydroelectric units. The modernization projects resulted in 447 MW of increased capacity from the conventional hydroelectric units, with an average efficiency gain of approximately five percent. In 2019, TVA began its transition to a new program, the Hydro Major Maintenance Program, intended to focus on life extension and addressing reliability risks that will support the preservation of TVA's hydroelectric fleet capacity. Hydroelectric generation will continue to be an important part of TVA's energy mix.
Other Renewable Energy Resources
TVA's renewable energy portfolio includes both TVA-owned assets and renewable energy purchases. TVA owns 14 solar sites with a total net summer capability of approximately 1 MW.
TVA tracks its renewable energy commitments and claims through the management of renewable energy certificates ("RECs"). The RECs, which each represent 1 MWh of renewable energy generation, are principally associated with wind, solar, biomass, and low-impact hydroelectric. TVA continues to evaluate ways to adjust to customer preferences and requirements for cleaner and greener energy, including the acquisition of RECs from renewable purchased power. These RECs can be sold to customers to meet their needs.
Diesel Generators
As of September 30, 2019, TVA had one diesel generator plant consisting of five units, and this facility accounted for 9
MW of summer net capability.
Distributed Energy Resources
Consumer desire for energy choice is, among other things, driving the expectation for flexible options in the electric industry. TVA and LPCs are working together to leverage the strengths of the Tennessee Valley public power model to provide economic, sustainable, and flexible distributed energy solutions. TVA will focus on the safety and reliability impacts of these resources as they are interconnected to the grid and will ensure that the pricing of electricity remains as low as feasible. Additional regulatory considerations and analysis may be required as the distributed energy resources ("DER") market, technologies, and programs evolve. TVA is working to develop pricing and regulatory structures with a deliberate and thoughtful analysis of each current and future program offering. This requires strong partnerships with LPCs to give customers choices and provide end-use consumers the flexibility they desire.
During its February 2019 meeting, the TVA Board approved new renewable power solutions, including a mid-scale option. The mid-scale option, also known as the Flexibility Research Project, is a joint project with LPCs to enable solutions for situations where the end-use consumer needs onsite renewable or distributed generation and for TVA to gain market knowledge and operational insights from these research projects. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Renewable Power Solutions.
Through the Home Uplift Program, TVA is partnering with LPCs, state and local governments, non-profit agencies, energy efficiency advocates, and the Tennessee Valley Public Power Association to complete home evaluations and make high-impact home energy upgrades for qualifying homeowners. In addition, TVA and LPCs conduct workshops to educate homeowners about low and no-cost energy efficiency upgrades that improve their quality of life.
TVA has encouraged the development of solar, wind, biomass, and low-impact hydroelectric generation systems across the Tennessee Valley through various current and former offerings. As of September 30, 2019, the combined participation for all such renewable solutions is 415 MW of installed operating capacity with nearly 685 MW of additional approved capacity. Additionally, TVA contracts for approximately 1,215 MW of operating wind capacity from outside the Tennessee Valley via power purchase agreements.
In May 2017, the TVA Board authorized up to $300 million to be spent over the next 10 years, subject to annual budget availability and necessary environmental reviews, to build an enhanced fiber optic network by adding up to 3,500 additional miles that will better connect its operational assets. Fiber is a vital part of TVA's modern communication infrastructure. The new fiber optic lines will improve the reliability and resiliency of the generation and transmission system while enabling the system to better accommodate DER as they enter the market.
New energy management systems and energy storage technologies present opportunities for more sophisticated and integrated operation of the entire grid. The advent of electric vehicles and small-scale renewable generation has hastened the development of energy storage technologies that have the potential to mitigate the intermittent supply issues associated with many renewable generation options. Implementation of these technologies in conjunction with two-way communication to the site creates the potential for more efficient usage of other DER on the grid.
TVA's Electric Vehicle ("EV") strategy is a staged approach that will evolve as the local EV market matures. Since 2011, TVA has focused on utilizing more EVs and installing charging stations inside the Tennessee Valley. This approach has
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enabled TVA to gain insights on the value and impact to utilities of large-scale electrification. TVA has also partnered with over 30 organizations across the State of Tennessee (known as the "Drive Electric Tennessee" collaborative) to create a roadmap to outline local market needs for widespread adoption. This foundational information is crucial as more affordable, longer range EVs come to the market in the next few years.
Onsite energy management technologies and the proliferation of companies interested in providing services to support and aggregate the impacts of such systems provide another DER opportunity. Such systems can afford the consumer benefits through reduced consumption, increased comfort, detailed energy use data, and savings from time-sensitive rate structures. TVA and LPCs must consider the integration of the impacts from changes in energy usage patterns resulting from the operation of such systems.
Demand response systems that take advantage of the increasing sophistication in communication to homes, businesses, and distribution system assets also afford the opportunity for more granular control of system demand. Technologies can manage individual customer systems to shift usage from peak to off-peak periods and create significant reductions in the need for peak generation output. More sophisticated distribution control systems can also lower peak demand through control of excess voltage on the grid on either a dispatchable or continuous basis.
TVA is leading an initiative to determine the value of DER for its system. Initial efforts are focused on small-scale distributed (rooftop) solar, but the efforts are general enough to allow for other distributed options. These efforts are ongoing, led by a team that includes technical support from the Electric Power Research Institute ("EPRI"), to develop a methodology to identify site preferences on the distribution systems of the LPCs. This work, along with locational analysis already completed by TVA, will help in placing utility-scale solar in furtherance of the IRP recommendations as well as distributed solar to meet the needs of LPCs. See Research and Development below.
Purchased Power and Other Agreements
TVA acquires power from a variety of power producers through long-term and short-term power purchase agreements ("PPAs") as well as through spot market purchases. During 2019, TVA acquired approximately 87 percent of the power that it purchased through the long-term PPA described below, including agreements for long-term renewable generation resources, approximately one percent through short-term PPAs, and approximately 12 percent on the spot market.
Renewable Power Purchase Agreements. In order to meet customer preferences and requirements for cleaner and greener energy, TVA has entered into certain PPAs with renewable resource providers during 2019. These agreements are part of progressive partnerships that align the core values of TVA and the public power model with the desire of TVA's customers for renewable energy. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Changing Customer Preferences — Renewable Power Purchase Agreements.
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A portion of TVA's capability provided by power purchase agreements is provided under contracts that expire between 2021 and 2042, and the most significant of these contracts are described in the table below.

Power Purchase Contracts At September 30, 2019
Type of Facility |  | Location |  | Summer Net Capability (MW) |  | Contract Termination Date
Lignite |  | Mississippi |  | 440 |  | 2032
Natural gas |  | Alabama |  | 720 |  | 2023
Natural gas |  | Alabama |  | 615 |  | 2026
Solar |  | Alabama |  | 75 |  | 2037
Solar(1) |  | Alabama |  | 227 |  | 2041
Solar(1) |  | Alabama |  | 150 |  | 2042
Solar |  | Tennessee |  | 53 |  | 2038
Solar |  | Tennessee |  | 4.5 |  | 2032
Solar(1) |  | Tennessee |  | 147 |  | 2042
Solar(1) |  | Tennessee |  | 150 |  | 2042
Landfill Gas |  | Tennessee |  | 4.8 |  | 2031
Hydroelectric(2) |  | Tennessee and Kentucky |  | 347 |  | Upon three years' notice
Wind |  | Iowa |  | 198 |  | 2031
Wind |  | Iowa |  | 101 |  | 2030
Wind |  | Kansas |  | 201 |  | 2032
Wind |  | Kansas |  | 165 |  | 2033
Wind |  | Illinois |  | 150 |  | 2032
Wind |  | Illinois |  | 200 |  | 2032
Wind |  | Illinois |  | 200 |  | 2033
Wind |  | Tennessee |  | 27 |  | 2025
Diesel |  | Tennessee |  | 23 |  | 2023
Diesel |  | Tennessee |  | 20 |  | 2021
Diesel |  | Tennessee |  | 8 |  | 2023
Diesel |  | Tennessee |  | 8 |  | 2028
Diesel |  | Mississippi |  | 20 |  | 2023
Diesel |  | Mississippi |  | 26 |  | 2028
Diesel |  | Alabama |  | 10 |  | 2028

Notes
(1) Power delivery is expected to commence in 2021.
(2) TVA's contract with Southeastern Power Administration ("SEPA") is for 405 MW of capacity; however, at September 30, 2019, TVA's capacity under the contract was 347 MW because of repairs being completed by the USACE. TVA expects this period of reduced capacity to be in effect until January 2020.
Under federal law, TVA is required to purchase energy from qualifying facilities (cogenerators and small power producers) at TVA's avoided cost of either generating this energy itself or purchasing this energy from another source. TVA fulfills this requirement through the Dispersed Power Production Program. As of September 30, 2019, there were 55 generation sources, with a combined qualifying capacity of 263 MW, whose power TVA purchases under this program.
Fuel Supply
General
TVA's consumption of various types of fuel depends largely on the demand for electricity by TVA's customers, the availability of various generating units, and the availability and cost of fuel. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations — Financial Results — Operating Expenses.
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Nuclear Fuel
Current Fuel Supply. Converting uranium to nuclear fuel generally involves four stages: the mining and milling of uranium ore to produce uranium concentrates; the conversion of uranium concentrates to uranium hexafluoride gas; the enrichment of uranium hexafluoride; and the fabrication of the enriched uranium hexafluoride into fuel assemblies. For its forward four-year (2020-2023) requirements, TVA currently has 100 percent of its uranium mining and milling, conversion services, enrichment services, and fabrication services requirements either in inventory or under contract with various suppliers. TVA anticipates being able to fill its needs beyond this period by normal contracting processes as market forecasts indicate that the fuel cycle components will be readily available. The net book value of TVA's nuclear fuel was $1.5 billion at both September 30, 2019 and 2018. See Note 15 — Risk Management Activities and Derivative Transactions — Counterparty Risk.
TVA, the DOE, and certain nuclear fuel contractors have entered into agreements providing for surplus DOE highly enriched uranium (uranium that is too highly enriched for use in a nuclear power plant) to be blended with other uranium. The enriched uranium that results from this blending process, which is called blended low-enriched uranium ("BLEU"), is fabricated into fuel that can be used in a nuclear power plant. This blended nuclear fuel was first loaded in a Browns Ferry reactor in 2005, and the last fuel under this program is currently being utilized. Under the terms of the interagency agreement between the DOE and TVA, the DOE participated in the savings generated by TVA's use of the BLEU. See Note 1 — Summary of Significant Accounting Policies — Blended Low-Enriched Uranium Program for a more detailed discussion of the BLEU project.
TVA, the DOE, and certain nuclear fuel contractors have entered into agreements, referred to as the Down-blend offering for Tritium ("DBOT"), 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. See Note 1 — Summary of Significant Accounting Policies — Down-blend Offering for Tritium for a more detailed discussion of the DBOT project.
Low-Level Radioactive Waste. Certain materials and supplies used in the normal operation of nuclear electrical generating units are potentially exposed to low levels of radiation. TVA sends shipments of low-level radioactive waste to burial facilities in Clive, Utah and Andrews, Texas. TVA is capable of storing some low-level radioactive waste at its own facilities for an extended period of time, if necessary.
Spent Nuclear Fuel. All three nuclear sites have dry cask storage facilities. Sequoyah will need additional capacity by 2028. Watts Bar will need additional capacity by 2041. Browns Ferry will need additional storage capacity by the end of 2020. A project is underway at Browns Ferry to build another independent spent fuel storage installation pad and is scheduled for completion by January 2020. To recover the cost of providing long-term, onsite storage for spent nuclear fuel, TVA filed a breach of contract suit against the U.S. in the Court of Federal Claims in 2001. As a result of this lawsuit and related agreements, TVA has collected approximately $304 million through 2019.
Tritium-Related Services. TVA and the DOE are engaged in a long-term interagency agreement under which TVA will, at the DOE's request, irradiate tritium-producing burnable absorber rods ("TPBARs") to assist the DOE in producing tritium for the Department of Defense ("DOD"). This agreement, which ends in 2035, requires the DOE to reimburse TVA for the costs that TVA incurs in connection with providing irradiation services and to pay TVA an irradiation services fee at a specified rate per TPBAR over the period when irradiation occurs.
In general, TPBARs are irradiated for one operating cycle, which lasts about 18 months. At the end of the cycle, TVA removes the irradiated rods and loads them into a shipping cask. The DOE then ships them to its tritium-extraction facility. TVA loads a fresh set of TPBARs into the reactor during each refueling outage. Irradiating the TPBARs does not affect TVA's ability to safely operate the reactors to produce electricity.
TVA has provided irradiation services using only Watts Bar Unit 1 since 2003. Although the interagency agreement provides for irradiation services to be performed at Watts Bar and Sequoyah, TVA expects the Watts Bar site to provide sufficient capacity to fulfill this agreement in the near term. The DOE notified TVA of future increased needs for tritium requiring the use of a second reactor. TVA submitted a license amendment to the NRC in December 2017 to authorize the irradiation of TPBARs in Watts Bar Unit 2. The NRC approved the license amendment request in May 2019.
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Natural Gas and Fuel Oil
During 2019, TVA purchased a significant amount of its natural gas requirements from a variety of suppliers under contracts with terms of up to three years and purchased substantially all of its fuel oil requirements on the spot market. The net book value of TVA's natural gas inventory was $15 million and $18 million at September 30, 2019 and 2018, respectively. The net book value of TVA's fuel oil inventory was $82 million and $84 million at September 30, 2019 and 2018, respectively. At September 30, 2019, 80 of the combustion turbines that TVA operates were dual-fuel capable, and TVA has fuel oil stored on each of these sites as a backup to natural gas.
TVA purchases natural gas from multiple suppliers on a daily, monthly, seasonal, and term basis. During 2019, daily, monthly, seasonal, and term contracts accounted for 21 percent, five percent, 30 percent, and 44 percent of purchases, respectively. TVA plans to continue using contracts of various lengths and terms to meet the projected natural gas needs of its natural gas fleet. During 2019, TVA transported natural gas on eight separate pipelines, with approximately 31 percent being transported on a single pipeline. During 2019, TVA maintained a total of approximately 1,405,000 million British thermal unit(s) ("mmBtu") per day of firm transportation capacity on six major pipelines, with approximately 33 percent of total firm transportation capacity being maintained on a single pipeline.
TVA utilizes natural gas storage services at seven facilities with a total capacity of 8.35 billion per cubic feet ("Bcf") of firm service and 2.30 Bcf of interruptible service to manage the daily balancing requirements of the eight pipelines used by TVA, with approximately 42 percent of the total storage capacity being maintained at a single facility. During 2019, storage levels were generally maintained at between 40 and 80 percent of the maximum contracted capacity at each facility. As TVA's natural gas requirements grow, it is anticipated that additional storage capacity may need to be acquired to meet the needs of the generating assets. In 2020, TVA does not expect to add a significant amount of firm capacity to its storage portfolio.
Coal
Coal consumption at TVA's coal-fired generating facilities during 2019 and 2018 was approximately 15 million tons and 17 million tons, respectively. At September 30, 2019 and 2018, TVA had 33 days and 30 days of system-wide coal supply at full burn rate, respectively, with net book values of $197 million and $164 million, respectively.
TVA utilizes both short-term and long-term coal contracts. During 2019, long-term contracts made up 82 percent of coal purchases, and short-term contracts accounted for the remaining 18 percent. TVA plans to continue using contracts of various lengths, terms, and coal quality to meet its expected consumption and inventory requirements. During 2019 and 2018, TVA purchased coal by basin as follows:
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The following charts present the proportion of each delivery method TVA utilizes for its coal supply for the periods indicated:
Generally, total system coal inventories were at or below target levels for 2019. TVA began 2019 with low coal inventories due to higher than expected utilization during the summer of 2018. Inventory balances were restored throughout the year to meet winter and summer peak demands.
Transmission
The TVA transmission system is one of the largest in North America. TVA's transmission system has 69 interconnections with 13 neighboring electric systems, and delivered nearly 158 billion kWh of electricity to TVA customers in 2019. In carrying out its responsibility for transmission grid reliability in the TVA service area, TVA has operated with 99.999 percent reliability since 2000 in delivering electricity to customers. See Item 2, Properties — Transmission Properties.
Pursuant to its Transmission Service Guidelines, TVA offers transmission services to eligible customers to transmit wholesale power in a manner that is comparable to TVA's own use of the transmission system. TVA has also adopted and operates in accordance with its published Transmission Standards of Conduct and separates its transmission function from its power marketing function.
TVA is subject to federal reliability standards that are set forth by the North American Electric Reliability Corporation ("NERC") and approved by FERC. These standards are designed to maintain the reliability of the bulk electric system, including TVA's generation and transmission system, and include areas such as maintenance, training, operations, planning, modeling, critical infrastructure, physical and cyber security, vegetation management, and facility ratings. TVA recognizes that reliability standards and expectations for transmission systems continue to become more complex and stringent.
Additional transmission upgrades may be required to maintain reliability. Upgrades may include enhancements to existing lines and substations or new installations as necessary to provide adequate power transmission capacity, maintain voltage support, and ensure generating plant and transmission system stability.
In May 2017, the TVA Board approved a $300 million, multi-year, strategic fiber optic initiative that will expand TVA's fiber capacity and improve the reliability and resiliency of the transmission system. The network expansion is designed to help meet the power system's growing need for bandwidth as well as accommodate the integration of new DER. As of September 30, 2019, TVA had installed 483 miles of fiber optic lines and spent $79 million on installation of the fiber optic lines. TVA expects to spend an additional $221 million to complete the project.
The TVA Board approved $245 million for the construction of a new system operations center. The new secured facility is being built to accommodate a new energy management system and to adapt to new regulatory requirements. The facility is expected to be constructed by 2021 and fully operational by 2023. As of September 30, 2019, TVA had spent approximately $14 million on the project and expects to spend an additional $231 million.
Weather and Seasonality
Weather affects both the demand for and the market prices of electricity. TVA's power system is generally a dual-peaking system in which the demand for electricity peaks during the summer and winter months to meet cooling and heating needs. TVA uses degree days to measure the impact of weather on its power operations. Degree days measure the extent to which the TVA system 23-station average temperatures vary from 65 degrees Fahrenheit. During 2019, TVA transitioned degree
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day calculation methodologies, moving from the average temperatures of the five largest cities in TVA's service area to the average temperatures of 23 stations throughout TVA's service area. This transition provides TVA with increased geographic granularity throughout its service territory and improves modeling accuracy. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations — Sales of Electricity.
Competition
TVA provides electricity in a service area that is largely free of competition from other electric power providers based on the provisions of the TVA Act. This service area is defined primarily by provisions of law and long-term contracts. The fence limits the region in which TVA or LPCs that distribute TVA power may provide power. The anti-cherrypicking provision limits the ability of others to use the TVA transmission system for the purpose of serving customers within TVA's service area. State service territory laws limit unregulated third parties' ability to sell electricity to consumers. All TVA wholesale power contracts are all requirements contracts. However, other utilities may use their own transmission lines to serve customers within TVA's service area, and third parties are able to avoid the restrictions on serving end-use customers by selling or leasing generating assets to a customer rather than selling electricity. These threats underscore the need for TVA to strategically price its products and services and design rates to be competitive. There have also been some efforts in the past to erode the anti-cherrypicking provision, and the protection of the anti-cherrypicking provision could be limited and perhaps eliminated by federal legislation at some time in the future.
TVA also faces competition in the form of emerging technologies. Improvements in energy efficiency technologies, smart technologies, and energy storage technologies may reduce the demand for centrally provided power. The growing interest by customers in generating their own power through DER has the potential to lead to a reduction in the load served by TVA as well as cause TVA to re-evaluate how it operates the overall grid system to continue to provide highly reliable power at affordable rates. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Distributed Energy Resources.
Finally, TVA and other utility companies are facing an evolving marketplace of increased competition driven by customer choice and behavior. As technology develops, consumers' demands for access to diverse products and services may increase, creating opportunities for growth with new products and services resulting from emerging technologies.
Research and Development
Investments in TVA's research portfolio are supported through partnership and collaboration with LPCs, EPRI, DOE, federal agencies, national labs, peer utilities, universities, industry vendors, participation in professional societies, and other research consortiums.
Annual investments made in science and technological innovation help meet future business and operational
challenges. Each year, TVA's annual research portfolio is updated based on a broad range of operational and industry drivers to assess key technology gaps, performance issues, or other significant issues, addressed through research and development. Core research activities directly support optimization of TVA's generation and transmission assets, air and water quality, energy utilization, and distributed/clean energy integration. TVA has launched a research program focused on evaluating the potential to deploy grid-scale battery energy storage technology to optimize the existing TVA generation assets and improve the resiliency of the transmission system. This research will guide future application of battery storage as part of the evolving bulk power system in the region.
TVA evaluates emerging energy efficiency and load management technologies for market and program readiness. Efforts are directed towards demonstrating and validating the performance, reliability, and consumer acceptance of new efficiency technologies, as well as the value of energy efficiency and load management technologies for the consumer, LPCs, and TVA.
TVA is assessing potential electrification programs that improve resource use and reduce environmental impacts (especially in the transportation sector). Assessments include a multi-stakeholder vision and roadmap effort aimed at identifying the path forward for electric vehicles in Tennessee. The approach provides for broad engagement from industry, government, and utilities that could be applied in other states in the TVA service territory. In addition, TVA is continuing its evaluation of potential electric vehicle adoption strategies through coordination of activities with EPRI and industry stakeholders related to operational fleet requirements. Additional areas of focus include LPC engagement on plug-in electric vehicle grid integration and readiness for various transportation electrification technologies. In addition, research in electrification applications on charging stations, impacts from charging stations to the power grid, refinement of power-system control processes, and development of smart charging strategies to maximize the potential of electricity to replace petroleum as the transportation fuel of choice.
TVA and LPCs engage in several initiatives related to grid modernization. Research includes technologies and applications advancement in intelligent transmission and distribution systems. Smart meter technology has the potential to shift usage patterns away from peak demand times which could change costs significantly. Additionally, intelligent transmission systems would give TVA the ability to nearly instantaneously diagnose problems, make corrections, and engage transmission and generation resources quickly so that power would keep flowing. This could promote reduced emissions, lower energy costs,
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and add greater flexibility to accommodate the new consumer-generated sources under TVA's renewable energy programs. See Power Supply and Load Management Resources — Distributed Energy Resources.
Finally, TVA is evaluating small clean power resources that can be aggregated to meet regular demand. Research efforts into clean DER seek to understand the scope and impact on operations and business economics and to develop strategies for adapting to the evolving electricity landscape in the Tennessee Valley. Battery storage and solar power models deployed in the Tennessee Valley are also being evaluated to better understand their impacts to the grid. Initial economic analyses have been conducted to identify the value of DER (particularly photovoltaic solar generation) to both TVA and the LPC system. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Distributed Energy Resources.
Flood Control Activities
The Tennessee River watershed has one of the highest annual rainfall totals of any watershed in the U.S., averaging 51 inches per year. During 2019, approximately 67 inches of rain fell in the Tennessee Valley. TVA manages the Tennessee River system in an integrated manner, balancing hydroelectric generation with navigation, flood damage reduction, water quality and supply, and recreation. TVA spills or releases excess water through its dams in order to reduce flood damage to the Tennessee Valley. TVA typically spills only when all available hydroelectric generating turbines are operating at full capacity and additional water still needs to be moved downstream.
Significant flooding occurred in portions of the Tennessee Valley in February 2019. During this time, the Tennessee Valley received 11.6 inches of rainfall, which was 269 percent of normal. Although many locations along the Tennessee River reached or exceeded flood stage, TVA's efforts, including storing water in large tributary reservoirs, accounted for approximately $1.6 billion in avoided damages in areas such as Chattanooga, Tennessee.
Environmental Stewardship Activities
TVA's mission includes managing the Tennessee River, its tributaries, and federal lands along the shoreline to provide, among other things, year-round navigation, flood damage reduction, affordable and reliable electricity, recreational opportunities, adequate water supply, improved water quality, and natural resource protection. There are 49 dams that comprise TVA's integrated reservoir system. Each dam may also have ancillary structures used to support or assist the main dam's function. The reservoir system provides approximately 800 miles of commercially navigable waterways and also provides significant flood reduction benefits both within the Tennessee River system and downstream on the lower Ohio and Mississippi Rivers. The reservoir system also provides a water supply for residential and industrial customers, as well as cooling water for TVA's coal-fired plants, combined cycle plants, and nuclear power plants. TVA's Environmental Policy provides objectives for an integrated approach related to providing cleaner, reliable, and low-cost energy, supporting sustainable economic growth, and engaging in proactive environmental stewardship in a balanced and ecologically sound manner. The Environmental Policy provides additional direction in several environmental stewardship areas, including water resource protection and improvements, sustainable land use, and natural resource management.
TVA serves the people of the TVA region through the integrated management of the Tennessee River system and public lands, which include approximately 11,000 miles of shoreline; 650,000 surface acres of reservoir water; and 293,000 acres of reservoir lands. TVA accomplishes this mission and supports the objectives of the TVA Environmental Policy through implementation of its natural resources stewardship strategy. Within this strategy, TVA confirms a desire to remain agile, balance competing demands, and be a catalyst for collaboration in order to protect and enhance biological, cultural, and water resources as well as create and sustain destinations for recreation and opportunities for learning and research. As part of the strategy, TVA intends to assist water-based community development with issuing permits, technical support, and land agreements using planning, clear regulations, meaningful guidelines, and consistent enforcement. Additional guidance for carrying out many of TVA's essential stewardship responsibilities is provided in TVA's Natural Resource Plan ("NRP"). TVA is currently updating its NRP. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Natural Resource Plan.
Economic Development Activities
Economic development, along with energy production and environmental stewardship, is one of the primary statutory purposes of TVA. TVA works with its LPCs; regional, state, and local agencies; and communities to showcase the advantages available to businesses locating or expanding in TVA's service area. TVA's primary economic development goals are to recruit companies to locate in the Tennessee Valley, encourage expansion of existing business and industry that provide quality jobs, and assist communities in the Tennessee Valley with economic growth opportunities. TVA seeks to meet these goals through a combination of initiatives and partnerships designed to provide financial assistance, technical services, industry expertise, and site-selection assistance to new and existing businesses.
Economic development programs developed by TVA include those which focus on supporting all communities, including rural and economically distressed communities, across the Tennessee Valley by working in close partnership with other federal and state organizations. TVA also jointly offers incentive programs with participating LPCs. These programs offer competitive incentives to existing and potential power customers in certain business sectors that make multi-year commitments to invest in
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the Tennessee Valley. In addition to financial support for these programs, TVA offers resources to communities and economic developers in the areas of recruitment, leadership development, industrial product preparedness (sites and buildings), planning, and project assistance.
TVA's economic development efforts helped recruit or expand 215 companies into the TVA service area during 2019. These companies announced capital investments of over $8.9 billion and the expected creation and/or retention of approximately 66,500 jobs.
Regulation
Congress
TVA exists pursuant to the TVA Act as enacted by Congress and carries on its operations in accordance with this legislation. Congress can enact legislation expanding or reducing TVA's activities, change TVA's structure, and even eliminate TVA. Congress can also enact legislation requiring the sale of some or all of the assets TVA operates or reduce the U.S.'s ownership in TVA. To allow TVA to operate more flexibly than a traditional government agency, Congress exempted TVA from all or parts of certain general federal laws that govern other agencies, such as federal labor relations laws and the laws related to the hiring of federal employees, the procurement of supplies and services, and the acquisition of land. Other federal laws enacted since the creation of TVA that are applicable to other agencies have been made applicable to TVA, including those related to paying employees overtime and protecting the environment, cultural resources, and civil rights.
Securities and Exchange Commission
Section 37 of the Securities Exchange Act of 1934 (the "Exchange Act") requires TVA to file with the SEC such periodic, current, and supplementary information, documents, and reports as would be required pursuant to Section 13 of the Exchange Act if TVA were an issuer of a security registered pursuant to Section 12 of the Exchange Act. Section 37 of the Exchange Act exempts TVA from complying with Section 10A(m)(3) of the Exchange Act, which requires each member of a listed issuer's audit committee to be an independent member of the board of directors of the issuer. Since TVA is an agency and instrumentality of the U.S., securities issued or guaranteed by TVA are "exempted securities" under the Securities Act of 1933, as amended (the "Securities Act"), and may be offered and sold without registration under the Securities Act. In addition, securities issued or guaranteed by TVA are "exempted securities" and "government securities" under the Exchange Act. TVA is also exempt from Sections 14(a)-(d) and 14(f)-(h) of the Exchange Act (which address proxy solicitations) insofar as those sections relate to securities issued by TVA, and transactions in TVA securities are exempt from rules governing tender offers under Regulation 14E of the Exchange Act. Also, since TVA securities are exempted securities under the Securities Act, TVA is exempt from the Trust Indenture Act of 1939 insofar as it relates to securities issued by TVA, and no independent trustee is required for these securities.
Federal Energy Regulatory Commission
Under the FPA, TVA is not a "public utility," a term which primarily refers to investor-owned utilities. Therefore, TVA is not subject to the full jurisdiction that FERC exercises over public utilities under the FPA. TVA is, however, an "electric utility" and a "transmitting utility" as defined in the FPA and, thus, is directly subject to certain aspects of FERC's jurisdiction. Under the FPA, for example, TVA (1) must comply with certain standards designed to maintain transmission system reliability, (2) can be ordered to interconnect its transmission facilities with the electrical facilities of independent generators and of other electric utilities that meet certain requirements, (3) can be ordered to transmit wholesale power provided that the order (a) does not impair the reliability of the TVA or surrounding systems and (b) meets the applicable requirements concerning terms, conditions, and rates for service, as well as the anti-cherrypicking provision, (4) is subject to FERC review of the transmission rates and the terms and conditions of service that TVA provides, and (5) is prohibited from (a) reporting false information on the price of electricity sold at wholesale or the availability of transmission capacity to a federal agency with intent to fraudulently affect the data being compiled by the agency and (b) using manipulative or deceptive devices or contrivances in connection with the purchase or sale of power or transmission services subject to FERC's jurisdiction.
In addition, the FPA provides FERC with authority (1) to order refunds of excessive prices on short-term sales (transactions lasting 31 days or less) by all market participants, including TVA, in price gouging situations if such sales are through an independent system operator or regional transmission organization under a FERC-approved tariff, (2) to issue regulations requiring the reporting, on a timely basis, of information about the availability and prices of wholesale power and transmission service by all market participants, including TVA, (3) to investigate electric industry practices, including TVA's operations that are subject to FERC's jurisdiction, and (4) to impose civil penalties of up to $1 million per day for each violation of the provisions of the FPA discussed in the prior paragraph that are applicable to TVA. Criminal penalties may also result from such violations.
Finally, while not required to do so, TVA has elected to implement various FERC orders and regulations pertaining to public utilities on a voluntary basis to the extent that they are consistent with TVA's obligations under the TVA Act.
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Nuclear Regulatory Commission
TVA operates its nuclear facilities in a highly regulated environment and is subject to the oversight of the NRC, an independent federal agency that sets the rules that users of radioactive materials must follow. The NRC has broad authority to impose requirements relating to the licensing, operation, and decommissioning of nuclear generating facilities. In addition, if TVA fails to comply with requirements promulgated by the NRC, the NRC has the authority to impose fines, shut down units, or modify, suspend, or revoke TVA's operating licenses.
Environmental Protection Agency
TVA is subject to regulation by the EPA in a variety of areas, including air quality control, water quality control, and management and disposal of solid and hazardous wastes. See Environmental Matters below.
States
The Supremacy Clause of the U.S. Constitution prohibits states, without federal legislative consent, from regulating the manner in which the federal government conducts its activities. As a federal agency, TVA is exempt from regulation, control, and taxation by states except in certain areas where Congress has clearly made TVA subject to state regulation. See Environmental Matters below.
Other Federal Entities
TVA's activities and records are also subject to review to varying degrees by other federal entities, including the Government Accountability Office and the Office of Management and Budget ("OMB"). There is also an Office of the Inspector General which reviews TVA's activities and records.
Taxation and 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, however, does require TVA to make tax equivalent payments to states and counties in which TVA conducts power operations or in which TVA has acquired properties previously subject to state and local taxation. The total amount of these payments is five percent of gross revenues from the sale 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. Except for certain direct payments TVA is required to make to counties, distribution of tax equivalent payments within a state is determined by individual state legislation.
Environmental Matters
TVA's activities, particularly its power generation activities, are subject to comprehensive regulation under environmental laws and regulations relating to air pollution, water pollution, and management and disposal of solid and hazardous wastes, among other issues. Emissions from all TVA-owned and operated units (including small combustion turbine units of less than 25 MW) have been reduced from historic peaks. Emissions of nitrogen oxide ("NO x") have been reduced by 96 percent below peak 1995 levels and emissions of sulfur dioxide ("SO 2") have been reduced by 99 percent below 1977 levels through CY 2018. For CY 2018, TVA's emission of carbon dioxide ("CO 2") from its sources was 52 million tons, a 51 percent reduction from 2005 levels. This amount includes 5,037 tons from units rated at less than 25 MW. To remain consistent and to align with the EPA's reporting requirements, TVA intends to continue reporting CO 2 emissions on a calendar year basis.
Clean Air Act
The CAA establishes a comprehensive program to protect and improve the nation's air quality and control sources of air pollution. The major CAA programs that affect TVA's power generation activities are described below.
National Ambient Air Quality Standards. The CAA requires the EPA to set National Ambient Air Quality Standards ("NAAQS") for certain air pollutants. The EPA has done this for ozone, particulate matter ("PM"), SO 2, nitrogen dioxide ("NO 2"), carbon monoxide, and lead. Over the years, the EPA has made the NAAQS more stringent. Each state must develop a plan to be approved by the EPA for achieving and maintaining NAAQS within its borders. These plans impose limits on emissions from pollution sources, including TVA fossil fuel-fired plants. Areas meeting a NAAQS are designated as attainment areas. Areas not meeting a NAAQS are designated as non-attainment areas, and more stringent requirements apply in those areas, including stricter controls on industrial facilities and more complicated permitting processes. TVA fossil fuel-fired plants can be impacted by these requirements. All TVA generating units are located in areas designated as in attainment with NAAQS.
Cross-State Air Pollution Rule. The EPA issued the Cross-State Air Pollution Rule ("CSAPR") in July 2011 requiring several states in the eastern U.S. to improve air quality by reducing power plant emissions that contribute to pollution in other states. In 2016, the EPA issued an update to CSAPR to address cross-state air pollution (the "CSAPR Update Rule"). The EPA subsequently issued an additional rule to resolve any remaining cross-state air pollutant issues ("CSAPR Close-Out Rule"). The
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U.S. Court of Appeals for the District of Columbia Circuit ("D.C. Circuit") has remanded a portion of the CSAPR Update Rule back to the EPA to address its failure to require upwind states to eliminate substantial contributions to downwind nonattainment by the statutory deadline. The D.C. Circuit also vacated the CSAPR Close-Out Rule. TVA has not had and does not currently anticipate significant changes to its operations based on the CSAPR Update Rule and CSAPR Close-Out Rule in its current form.
Mercury and Air Toxics Standards for Electric Utility Units. Following litigation over the Mercury and Air Toxics Standards ("MATS") and the question of whether the EPA was required to consider cost before deciding whether the regulation of hazardous air pollutants ("HAP") emitted from steam electric utilities was appropriate and necessary, the EPA released a proposed finding that it is not appropriate and necessary to regulate HAP emissions from steam electric utilities. However, the EPA also proposed that notwithstanding this new finding, it would not remove electric generating units from the source categories listed under Section 112 of the CAA and it would not rescind the MATS requirements. Additionally, the EPA proposed to find that further restrictions on HAP emissions are not warranted upon conducting a residual risk and technology review for this source category. Until a final rule is issued, specific impacts to TVA cannot be determined; however, as proposed, the rule is not expected to change TVA's MATS compliance requirements or strategy.
Environmental Agreements. See Note 22 — Commitments and Contingencies — Legal Proceedings — Environmental Agreements for a discussion of the Environmental Agreements, which discussion is incorporated herein by reference.
Acid Rain Program. The Acid Rain Program is intended to help reduce emissions of SO 2 and NO x, which are the primary pollutants implicated in the formation of acid rain. The program includes a cap-and-trade emission reduction program for SO 2 emissions from power plants. TVA continues to reduce SO 2 and NO x emissions from its coal-fired plants, and the SO 2 allowances allocated to TVA under the Acid Rain Program are sufficient to cover the operation of its coal-fired plants. In the TVA service area, the limitations imposed on SO 2 and NO x emissions by the CSAPR program are more stringent than the Acid Rain Program. Therefore, TVA forecasts that the Acid Rain Program will not impose any additional material requirements on TVA.
Regional Haze Program. The EPA issued the Clean Air Visibility Rule, which required certain older sources to install best available retrofit technology. No additional controls or lower operating limits are required for any TVA units to meet best available retrofit technology requirements. In January 2017, the EPA published the final rule that changed some of the requirements for Regional Haze State Implementation Plans ("SIPs"). TVA does not expect significant impacts to its operations from these changes, but specific impacts cannot be determined until future Regional Haze SIPs are developed.
Opacity. Opacity, or visible emissions, measures the denseness (or color) of power plant plumes and has traditionally been used by states as a means of monitoring good maintenance and operation of particulate control equipment. Under some conditions, retrofitting a unit with additional equipment to better control SO 2 and NO x emissions can adversely affect opacity performance, and TVA and other utilities have addressed this issue. The evaluation of utilities' compliance with opacity requirements is coming under increased scrutiny, especially during periods of startup, shutdown, and malfunction. Historically, SIPs developed under the CAA typically excluded periods of startup, shutdowns, and malfunctions, but in June 2015, the EPA finalized a rule to eliminate such exclusions. The EPA rule required states to modify their implementation plans by November 2016. Kentucky, Tennessee, and Mississippi submitted implementation plans, but Alabama has not. Environmental petitioners and several states filed petitions for judicial review of the EPA final rule before the D.C. Circuit. In April 2017, the D.C. Circuit, at the request of the new EPA Administrator, ordered this litigation to be suspended pending the EPA's review to determine whether to reconsider all or part of the rule. TVA does not expect significant impacts from these rule changes.
Petition to Expand the Ozone Transport Region. In December 2013, eight of the twelve states that make up the Ozone Transport Region ("OTR") submitted a petition requesting the EPA to add nine states, including Kentucky and Tennessee, to the OTR. If states within TVA's service territory were included in the OTR, TVA would be required to further reduce NO x emissions. Six of the states filed suit when the EPA failed to act on the petition. In January 2017, the EPA subsequently published a notice in the Federal Register proposing to deny the petition on the basis that the CAA provides other options. The EPA then denied the petition in October 2017. In December 2017, the eight petitioning states filed in the D.C. Circuit a petition for judicial review of the EPA's denial of the petition to add states to the OTR. On April 23, 2019, the D.C. Circuit denied the petition for judicial review of the EPA's refusal to expand the OTR to include nine additional states.
Kentucky Startup/Shutdown Regulations. In April 2018, the Kentucky Division for Air Quality published final revised startup/shutdown regulations for new and existing indirect heat exchangers. Shawnee Fossil Plant ("Shawnee") and Paradise have boilers which will be subject to these rules when incorporated into their air permits. The revised rules do not significantly impact operations at Shawnee or Paradise.
Kentucky State Implementation Plan to Address Downwind Ozone Impacts. Emissions from utility units in Kentucky that contribute to ozone are already limited by the CSAPR Update Rule and are declining. In February 2018, Kentucky submitted a proposed revision to its SIP to address downwind state ozone impacts. The proposed SIP did not require emission reductions beyond current requirements, and in July 2018, the EPA issued a final rule approving Kentucky's revised SIP. No additional emission reductions are required by the SIP for TVA's Kentucky generating units.
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New York Petition to Address Impacts from Upwind High Emitting Sources. In March 2018, the State of New York filed a petition with the EPA under Section 126(b) of the CAA to address ozone impacts on New York from the NO x emissions from sources emitting at least 400 tons of NO x in CY 2017 from nine states including Kentucky. The New York petition requests that the EPA require daily NO x limits for utility units with SCRs such as Paradise Unit 3 and emission reductions from utility units without SCRs such as Shawnee Units 2, 3 and 5-9. Kentucky utility unit NO x emissions are already limited by the CSAPR Update Rule and are declining, and current EPA modeling projects no additional requirements to reduce Kentucky NO x emissions are necessary. During its February 2019 meeting, the TVA Board approved the retirement of Paradise Unit 3 by December 2020. On September 20, 2019, the EPA finalized its denial of New York's petition because the state did not demonstrate, and the EPA could not independently establish, that sources in the states listed in the petition contribute to exceedances of the 2008 and 2015 ozone NAAQS in New York. On October 29, 2019, the state of New York filed a petition in the D.C. Circuit for judicial review of the EPA's denial of the petition. Specific impacts to TVA as a result of the filing of the petition for judicial review cannot be determined at this time.
Affordable Clean Energy Rule. On June 19, 2019, the EPA finalized the final Affordable Clean Energy ("ACE") rule and repealed the EPA's previous regulation addressing greenhouse gas ("GHG") emissions from existing fossil fuel-fired units. The ACE rule establishes guidelines for GHG emissions from existing coal-fired units based on efficiency improvements that can be achieved at those units at reasonable cost. States are required to apply the emission guidelines to coal-fired units within their respective jurisdictions and take into account the remaining useful lives of those units. The impact of the ACE rule on TVA's coal-fired units cannot be determined until Tennessee and Kentucky submit to the EPA their SIPs implementing guidelines in the ACE rule and the EPA approves these SIPs. The ACE rule allows states three years to submit their SIPs and allows the EPA 18 months for approval.
New Source Performance Standards. On December 6, 2018, the EPA proposed revisions to the GHG emission standards for new, modified, and reconstructed electric utility generating units that were finalized by the EPA in October 2015. For coal-fired units, the EPA proposes to revise the current new source standards such that carbon capture and sequestration technology is no longer necessary to meet the standards of performance that reflect the best system of emission reduction. The resulting limits are less stringent than limits under the current rule and can be met by modern coal-fired units (e.g., supercritical steam generators) in combination with best operating practices, but without carbon capture and sequestration. The EPA is not proposing to revise the new source performance standard for GHG emission from gas-fired units. If finalized as proposed, the revisions are not expected to significantly impact TVA since TVA does not currently plan to construct, modify, or reconstruct any coal-fired units.
Maryland Petition to Address Impacts from Upwind Electric Generating Units. In September 2017, the State of Maryland filed a lawsuit against the EPA for failing to act within 60 days on Maryland's petition under Section 126 of the CAA to address ozone impacts on Maryland from the NO x emissions of 36 electric generating units, including TVA's Paradise coal-fired Unit 3. Paradise coal-fired Unit 3 is equipped with a SCR that TVA continuously operates to the greatest extent technically practicable in order to minimize NO x emissions. The EPA has denied the petition because existing regulations already address emissions from the generating units at issue. On October 15, 2018, the State of Maryland filed a petition for judicial review with the D.C. Circuit asking the court to review the EPA's decision.
Climate Change
Executive Actions. In March 2017, President Trump issued Executive Order ("EO") 13783, "Promoting Energy Independence and Economic Growth." The EO reversed or altered many actions taken by the federal government in the last four years of the Obama Administration to address climate change and mandates that federal agencies review existing regulations and actions that potentially burden energy development and use. Several EOs, policy statements, and reports that established climate change objectives were rescinded or revoked. EO 13783 did not mandate that the EPA reconsider its finding under the CAA that GHG emissions cause climate change and therefore endanger public health and the environment.
While EO 13783 requires review of all agency actions that potentially burden the safe, efficient development of domestic energy resources, the final specific requirements and impacts from implementation of this EO are not possible to predict at this time. It is likely that there will be some delay in the development of future GHG reduction requirements.
In May 2018, EO 13834, "Efficient Federal Operations," was signed. EO 13834 emphasizes meeting statutory requirements and gives agencies greater flexibility and discretion to decide how best to improve operations in order to "optimize energy and environmental performance, reduce waste, and cut costs." It also calls on the White House Council of Environmental Quality to streamline pre-existing environmental orders by "refocusing agencies on cost-effectively meeting mandates and goals" established by law. The order seeks to consolidate requirements related to energy and water efficiency, high performance buildings, renewable energy consumption, and federal vehicle fleet management. TVA consistently seeks to improve its operations in order to optimize energy and environmental performance and does not anticipate significant changes in its planning or operations as a result of the new EO.
International Accords. In September 2016, the U.S. formally accepted the Paris Agreement. The agreement met the threshold of at least 55 countries that account for at least 55 percent of global GHG emissions and formally entered into force in November 2016. The durability of the Paris Agreement commitments is uncertain after President Trump's announcement in
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June 2017 that the U.S. would withdraw from the agreement. On November 4, 2019, the United States formally notified the United Nations that it would withdraw from the agreement. Under the terms of the agreement, the effective date for the withdrawal will be November 4, 2020. Specific impacts to TVA cannot be determined at this time.
In response to President Trump's Paris withdrawal announcement, 25 states have formed the U.S. Climate Alliance, a bipartisan coalition of governors committed to reducing GHG emissions consistent with the goals of the Paris Agreement. North Carolina and Virginia are the only states in the TVA region that are U.S. Climate Alliance members. Among other commitments, each state commits to implement policies that advance the goals of the Paris Agreement, aiming to reduce GHG emissions by at least 26-28 percent below CY 2005 levels by CY 2025 and to accelerate new and existing policies to reduce carbon pollution and promote clean energy deployment at the state and federal level. In June 2017, America's Pledge was announced as a collaborative opportunity for these states to work with U.S. cities and businesses representing more than half of the U.S. economy. In September 2018, America's Pledge released its economy-wide policy analysis with recommendations of how states, cities, businesses, and other stakeholders can influence U.S. decarbonization. It is premature to determine potential impacts to TVA.
Litigation. In addition to legislative activity, climate change issues have been the subject of a number of lawsuits, including lawsuits against TVA. See Note 22 for additional information.
Indirect Consequences of Regulation or Business Trends. Legal, technological, political, and scientific developments regarding climate change may create new opportunities and risks. The potential indirect consequences could include an increase or decrease in electricity demand, increased demand for generation from alternative energy sources, and subsequent impacts to business reputation and public opinion. See Power Supply and Load Management Resources above.
Physical Impacts of Climate Change. TVA manages the potential effects of climate change on its mission, programs, and operations within its environmental management processes. The goal of the adaptation planning process is to ensure TVA continues to achieve its mission and program goals and to operate in a secure, effective, and efficient manner in a changing climate by integrating climate change adaptation efforts in coordination with state and local partners, tribal governments, and private stakeholders. TVA's Climate Change Adaptation Plan was last updated in June 2018.
Actions Taken by TVA to Reduce GHG Emissions. TVA has reduced GHG emissions from both its generation stations and its operations. As discussed earlier in this Item 1, Business, recent TVA Board actions have focused on TVA's plan to balance its coal-fired generation by increasing its nuclear capacity, modernizing its hydroelectric generation system, increasing natural gas-fired generation, installing emission control equipment on certain of its coal-fired units, increasing its purchases of renewable energy, building solar facilities, and investing in energy efficiency initiatives to reduce energy use in the Tennessee Valley. Additionally, TVA has invested to reduce energy use in its operations. The combination of more stringent environmental regulations, lower natural gas prices, and lower demand for energy across the Tennessee Valley has reduced the utilization of coal-fired generation. These factors have resulted in lower CO 2 emissions from the TVA system.
Renewable/Clean Energy Standards
Twenty-nine states and the District of Columbia have established enforceable or mandatory requirements for electric utilities to generate a certain amount of electricity from renewable sources. One state within the TVA service area, North Carolina, has a mandatory renewable standard that, while not applying directly to TVA, does apply to TVA's LPCs serving retail customers in that state. TVA's policy is to provide compliance assistance to any distributor of TVA power, and TVA is providing assistance to the covered LPCs that sell TVA power in North Carolina. Likewise, the Mississippi Public Service Commission adopted an energy efficiency rule applying to electric and natural gas providers in the state, and TVA is supplying information on participation in TVA's energy efficiency programs to support the covered Mississippi LPCs.
Water Quality Control Developments
Cooling Water Intake Structures. In May 2014, the EPA released a final rule under Section 316(b) of the Clean Water Act relating to cooling water intake structures ("CWIS") for existing power generating facilities. The rule requires changes in CWIS used to cool the vast majority of coal, gas, and nuclear steam-electric generating plants and a wide range of manufacturing and industrial facilities in the U.S. The final rule requires CWIS to reflect the best technology available for minimizing adverse environmental impacts, primarily by reducing the amount of fish and shellfish that are impinged or entrained at a cooling water intake structure. These new requirements will potentially affect a number of TVA's fossil- and nuclear-fueled facilities and will likely require capital upgrades to ensure compliance. Most TVA facilities are projected to require retrofit of CWIS with "fish-friendly" screens and fish return systems to achieve compliance with the new rule. The rule is being implemented through permits issued under the National Pollutant Discharge Elimination System ("NPDES") in Section 402 of the Clean Water Act. State agencies administer the NPDES permit program in most states including those in which TVA's facilities are located. In addition, the responsible state agencies must provide all permit applications to the U.S. Fish & Wildlife Service for a 60-day review prior to public notice and an opportunity to comment during the public notice. As a result, the permit may include requirements for additional studies of threatened and endangered species arising from U.S. Fish & Wildlife Service comments and may require additional measures be taken to protect threatened and endangered species and critical habitats directly or indirectly related to the plant cooling water intake. TVA's review of the final rule indicates that the rule offers adequate
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flexibility for cost-effective compliance. The required compliance timeframe is linked to plant specific NPDES permit renewal cycles (i.e., technology retrofits), and compliance is expected to be required in the CYs 2022-2024 timeframe.
Hydrothermal Discharges. The EPA and many states continue to focus regulatory attention on potential effects of hydrothermal discharges. Many TVA plants have variances from thermal standards under Section 316(a) of the Clean Water Act that are subject to review as NPDES permits are renewed. Specific data requirements in the future will be determined based on negotiations between TVA and regulators. If plant thermal limits are made more stringent, TVA may have to install cooling towers at some of its plants and operate installed cooling towers more often. This could result in a substantial cost to TVA.
Steam-Electric Effluent Guidelines. In 2015, the EPA revised existing steam-electric effluent limitation guidelines ("ELGs"), which regulate water discharge pollutants and require the application of certain pollutant control technologies. The 2015 ELGs establish more stringent performance standards for existing and new sources and will require major upgrades to wastewater treatment options at all coal-fired plants. Compliance with new requirements was originally required in the CYs 2018-2023 timeframe, but the EPA delayed the compliance for flue gas desulfurization ("FGD") wastewater and bottom ash transport water until CYs 2020-2023 to allow the EPA time to review and potentially revise the ELGs with regard to these waste streams.
In August 2017, the EPA Administrator announced his decision to conduct a rulemaking to potentially revise the new, more stringent effluent limitations that apply to bottom ash transport water and FGD wastewater in the CY 2015 ELG rule. In April 2019, the United States Court of Appeals for the Fifth Circuit ("Fifth Circuit") remanded portions of the 2015 ELG because it determined that some of the standards did not comply with statutory requirements. The EPA proposed revised ELGs for bottom ash transport water and FGD wastewater on November 4, 2019, but did address the portions of the ELG that were remanded by the Fifth Circuit.
The primary impact for TVA is on the operation of existing coal-fired generation facilities. The proposed revised ELGs could impact long-term investment decisions being made relative to the long-term compliance and operability of these plants. The proposed revisions may require TVA to install additional wastewater treatment systems for FGD wastewater and bottom ash transport water and TVA could incur substantial costs to comply with the new rule. The proposed revision also includes a subcategory for which the Cumberland Fossil Plant (“Cumberland”) would qualify that provides TVA greater flexibility in meeting the ELGs. However, given that these are proposed rules, it is unclear what the final impact to TVA will be. The proposed revisions may require TVA to install additional wastewater treatment systems for FGD wastewater and bottom ash transport water and TVA could incur substantial costs to comply with the new rule.
Other Clean Water Act Requirements. As is the case in other industrial sectors, TVA and other utilities are also facing more stringent requirements related to the protection of wetlands, reductions in storm water impacts from construction activities, new water quality criteria for nutrients and other pollutants, new wastewater analytical methods, and regulation of pesticide discharges.
Cleanup of Solid and Hazardous Wastes
Liability for releases and cleanup of hazardous substances is imposed under 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 Sites. TVA operations at some of its facilities have resulted in contamination that TVA is addressing including at TVA's Environmental Research Center at Muscle Shoals, Alabama. At September 30, 2019, TVA's estimated liability for cleanup and similar environmental work for those sites for which sufficient information was available to develop a cost estimate is approximately $15 million and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheet. In addition, the ERC has an active groundwater monitoring program as part of a Resource Conservation and Recovery Act ("RCRA") Corrective Action Permit.
Non-TVA Sites. TVA is aware of alleged hazardous-substance releases at certain non-TVA areas for which it may have some liability. See Note 22 — Commitments and Contingencies — Environmental Matters.
Coal Combustion Residuals. The EPA published its final rule governing CCR in April 2015. The rule regulates CCR as nonhazardous waste under Subtitle D of the RCRA. While states may adopt the rule's requirements into their regulatory programs, the rule does not require states to adopt the requirements. The initial version of the rule provided for self-implementation by utilities and allows enforcement through citizen suits in federal court. The Water Infrastructure Improvements for the Nation Act ("WIIN Act") subsequently allowed state or federal-based permitting to implement the CCR rule as an alternative to self-implementation and citizen suits. The rule, which became effective in October 2015, has later effective dates for certain provisions. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Generation Resources — Coal Combustion Residual Facilities for a discussion of the impact on TVA's operations, including the cost and timing estimates of related projects.
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In July 2018, the EPA issued a final rule which provided additional flexibility and an extension of certain deadlines. On March 13, 2019, the D.C. Circuit granted the EPA's request to remand this final rule to allow the EPA to reconsider the amendments to the CCR Rule. The remand also allows the EPA additional time to complete a new rulemaking to establish revised timelines for unlined impoundments to initiate closure and to reexamine the October 2020 deadline for closing some unlined impoundments. On August 14, 2019, the EPA issued a proposed rule to amend portions of the CCR Rule regarding beneficial use, temporary piles, and public access to information. As a result of these developments, it is not possible to predict potential impacts on TVA.
On November 4, 2019, the EPA announced a proposed rule that will revise portions of the CCR Rule requiring closure of unlined surface impoundments. This proposal, if finalized, will require all unlined CCR surface impoundments to stop receiving CCR and non-CCR wastestreams and to initiate closure by no later than August 31, 2020. The proposed rule would allow a utility to demonstrate the need for a short-term extension to continue to use the unlined CCR surface impoundment until November 30, 2020 if the alternative disposal capacity (i.e., new landfills or non-CCR water management systems) is not complete. Additionally, the proposed rule provides a process for a utility to seek site-specific approval from the EPA to continue to use the unlined CCR surface impoundment until no later than October 15, 2023. TVA does not currently anticipate the proposed rule will have a significant impact because TVA is already planning to close its unlined CCR surface impoundments.
In August 2015, the Tennessee Department of Environment and Conservation ("TDEC") issued an order that (1) allowed TDEC to oversee TVA's implementation of the EPA's CCR rule and (2) required TVA to assess CCR contamination risks at seven of TVA's eight coal-fired plants in Tennessee and to remediate any unacceptable risks. The TDEC order does not allege that TVA is violating any CCR regulatory requirements nor does it assess TVA penalties. The TDEC order sets out an iterative process through which TVA and TDEC will identify and evaluate any CCR contamination risks and, if necessary, respond to such risks.
TVA has been involved in two lawsuits concerning CCR facilities at Gallatin. These lawsuits have been resolved. 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.
Groundwater Contamination. Environmental groups and state regulatory agencies are increasing their attention on alleged groundwater contamination associated with CCR management activities. As a result, TVA may have to change how it manages CCR at some of its plants, potentially resulting in higher costs. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Generation Resources — Coal Combustion Residual Facilities, Note 10 — Asset Retirement Obligations, and 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.
Environmental Investments
From 1970 to 2019, TVA spent approximately $6.8 billion on controls to reduce emissions from its coal-fired power plants. In addition, TVA has reduced emissions by idling or retiring coal-fired units and relying more on cleaner energy resources including natural gas and nuclear generation.
TVA currently anticipates spending significant amounts on environmental projects through 2024, including investments in new clean energy generation including renewables to reduce TVA's overall environmental footprint. TVA environmental project expenditures also result from coal-fired plant decommissioning and from effective ash management modernization. Based on TVA's decisions regarding certain coal-fired units, the amount and timing of expenditures could change. See Power Supply and Load Management Resources — Coal-Fired above and Estimated Required Environmental Expenditures below.
SO 2 Emissions and NO x Emissions. To reduce SO 2 emissions, TVA operates scrubbers on 19 of its coal-fired units and switched to lower-sulfur coal at 13 coal-fired units. To reduce NO x emissions, TVA operates SCRs on 19 coal-fired units, operates low-NO x burners or low-NO x combustion systems on 19 units, operates over-fire air on one cyclone unit, optimized combustion on six units, and operates NO x control equipment year round when units are operating (except during start-up, shutdown, and maintenance periods). TVA has also retired 33 of 59 coal-fired units. Except for seven units at Shawnee, the remaining coal-fired units have scrubbers and SCRs. See Power Supply and Load Management Resources — Coal-Fired above.
Particulate Emissions. To reduce particulate emissions of air pollutants, TVA has equipped all of its coal-fired units with scrubbers, mechanical collectors, electrostatic precipitators, and/or bag houses.
Greenhouse Gas Emissions. There could be additional material costs if further reductions of GHGs, including CO 2, are mandated by legislative, regulatory, or judicial actions and if more stringent emission reduction requirements for conventional pollutants are established. These costs cannot reasonably be predicted at this time because of the uncertainty of these actions. The EPA may issue regulations establishing more stringent air, water, and waste requirements, and these requirements could result in significant changes in the structure of the U.S. power industry, especially in the eastern half of the country.
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Estimated Required Environmental Expenditures
The following table contains information about TVA's current estimates on projects related to environmental laws and regulations.

Estimated Potential Environmental Expenditures(1)(2) At September 30, 2019 (in millions)
| 2020 |  | 2021 |  | Thereafter(3)(4) |  | Total
Coal combustion residual conversion program(5) | $ | 289 |  |  | $ | 290 |  |  | $ | 602 |  |  | $ | 1,181 |
Clean air control projects(6) | 24 |  |  | 37 |  |  | 81 |  |  | 142 |
Clean Water Act requirements(7) | 84 |  |  | 74 |  |  | 120 |  |  | 278 |

Notes
(1) These estimates are subject to change as additional information becomes available and as regulations change.
(2) These estimates include $254 million, $207 million, and $256 million for the remainder of 2020, 2021, and thereafter, respectively, in capital expenditures.
(3) See Note 22 — Commitments and Contingencies.
(4) These estimates include expenditures expected to be incurred during 2022, 2023, and 2024.
(5) Includes costs associated with pond closures, conversion of wet to dry handling, and landfill activities. TVA is continuing to evaluate the rules and their impact on its operations, including the cost and timing estimates of related projects. See Item 7 Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Generation Resources — Coal Combustion Residual Facilities and Note 12 — Asset Retirement Obligations.
(6) Includes air quality projects that TVA is currently performing to comply with existing air quality regulations, but does not include any projects that may be required to comply with potential GHG regulations or transmission upgrades.
(7) Includes projects that TVA is currently planning to comply with revised rules under the Clean Water Act regarding CWIS and ELGs for steam electric power plants.
Employees
On September 30, 2019, TVA had 10,009 employees, of whom 3,415 were trades and labor employees. Neither the federal labor relations laws covering most private sector employers nor those covering most federal agencies apply to TVA. However, the TVA Board has a long-standing policy of acknowledging and working with recognized representatives of its employees, and that policy is reflected in long-term agreements to recognize the unions (or their successors) that represent TVA employees. Federal law prohibits TVA employees from engaging in strikes against TVA.
ITEM 1A. RISK FACTORS
The risk factors described below, as well as the other information included in this Annual Report, should be carefully considered. Risks and uncertainties described in these risk factors could cause future results to differ materially from historical results as well as from the results anticipated in forward-looking statements. Although the risk factors described below are the ones that TVA considers significant, additional risk factors that are not presently known to TVA or that TVA presently does not consider significant may also impact TVA's business operations. See Forward Looking Information above for a description of some matters that could affect the below risks or generate new risks. Although the TVA Board has the authority to set TVA's own rates and may mitigate some risks by increasing rates, there may be instances in which TVA would be unable to partially or completely eliminate one or more of these risks through rate increases over a reasonable period of time or at all. Accordingly, the occurrence of any of the following could have a material adverse effect on TVA's cash flows, results of operations, and financial condition.
For ease of reference, the risk factors are presented in four categories: (1) regulatory, legislative, and legal risks, (2) operational risks, (3) financial, economic, and market risks, and (4) general business risks.
REGULATORY, LEGISLATIVE, AND LEGAL RISKS
New laws, regulations, or administrative orders, or congressional action or inaction, may negatively affect TVA's cash flows, results of operations, and financial condition, as well as the way TVA conducts its business.
Because TVA is a corporate agency and instrumentality established by federal law, it may be affected by a variety of laws, regulations, and administrative orders that do not affect other electric utilities. For example, federal legislation may expand or reduce TVA's activities, change its governance structure, require TVA to sell some or all of the assets that it operates, require TVA to take certain other operational or regulatory actions, reduce or eliminate the U.S.'s ownership of TVA, or even liquidate TVA. Additionally, Congress could act, or fail to take action, on various issues that may result in impacts to TVA, including but not limited to action or inaction related to the national debt ceiling or automatic spending cuts in government programs.
Although it is difficult to predict exactly how new laws, regulations, or administrative orders or congressional action or inaction may impact TVA, some of the possible effects are described below.
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TVA may become subject to additional environmental regulation.
New environmental laws, regulations, or orders may become applicable to TVA or the facilities it operates, and existing environmental laws or regulations may be revised or reinterpreted in a way that adversely affects TVA, including substantially increasing TVA's cost of operations or requiring significant capital expenditures. Possible areas of future laws or regulations include, but are not limited to, GHGs, CCR, ELGs, water quality, renewable energy portfolio standards, and natural gas production and transmission.
TVA's ability to control or allocate funds could be restricted.
Other federal entities may attempt to restrict TVA's ability to access or control its funds that are on deposit in TVA's account in the U.S. Treasury. For example, should the U.S. Treasury approach its debt ceiling, the U.S. Treasury might, as part of an effort to control cash disbursements, attempt to require TVA to receive approval before disbursement of funds from TVA's U.S. Treasury account. Additionally, the OMB might, in the event that automatic spending cuts go into effect, attempt to require TVA to reduce its budget by a specified percentage (although the legal applicability of such a situation to TVA would depend upon the wording of the legislation making the automatic spending cuts). Such attempts to restrict TVA's ability to control or allocate funds in those specific types of situations could adversely affect its cash flows, results of operations, and financial condition, its relationships with creditors, vendors, and counterparties, the way it conducts its business, and its reputation.
TVA may lose its protected service territory.
TVA's service area is defined primarily by provisions of law and long-term contracts. The fence limits the region in which TVA or LPCs which distribute TVA power may provide power. The anti-cherrypicking provision limits the ability of others to use the TVA transmission system for the purpose of serving customers within TVA's service area. State service territory laws limit unregulated third parties' ability to sell electricity to consumers. All current wholesale power contracts between TVA and LPCs are all requirements contracts. However, other utilities may use their own transmission lines to serve customers within TVA's service area, and third parties are able to avoid the restrictions on serving end-use customers by selling or leasing generating assets to a customer rather than selling electricity.
From time to time, there have been efforts to erode the protection of the anti-cherrypicking provision, and the protection of the anti-cherrypicking provision could be limited and perhaps eliminated by federal legislation at some time in the future. If federal legislation were to eliminate or reduce the coverage of the anti-cherrypicking provision but retain the fence, TVA could more easily lose customers that it could not replace within its specified service area. The loss of these customers could adversely affect TVA's cash flows, results of operations, and financial condition.
The TVA Board may lose its sole authority to set rates for electricity.
Under the TVA Act, the TVA Board has the sole authority to set the rates that TVA charges for electricity, and these rates are not subject to further review. If the TVA Board loses this authority or if the rates or the ratemaking process become subject to external review, there could be material adverse effects on TVA including, but not limited to, being unable to set rates at a level sufficient to generate adequate revenues to service TVA's financial obligations, properly operate and maintain its assets, and provide for reinvestment in its power program and becoming subject to additional regulatory oversight that could impede its ability to adapt its business to changing circumstances.
TVA may lose responsibility for managing the Tennessee River system.
TVA's management of the Tennessee River system is important to effectively operate its power system. TVA's ability to integrate management of the Tennessee River system with power system operations increases power system reliability and reduces costs. Restrictions on how TVA manages the Tennessee River system could negatively affect its operations, change the way it conducts such operations, or increase costs.
TVA may lose responsibility for managing real property currently under its control.
TVA's management of real property containing power generation and transmission structures as well as certain reservoir shorelines is important for navigation, flood control, and the effective operation of the power system. Restrictions on or the loss of the authority to manage these properties could negatively affect TVA's operations, change the way it conducts such operations, or increase costs.
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Existing laws, regulations, and orders may negatively affect TVA's cash flows, results of operations, and financial condition, as well as the way TVA conducts its business.
TVA is required to comply with comprehensive and complex laws, regulations, and orders. The costs of complying with these laws, regulations, and orders are expected to be substantial, and costs could be significantly more than TVA anticipates, especially in the environmental and nuclear areas. In addition, TVA is required to obtain numerous permits and approvals from governmental agencies that regulate its business, and TVA may be unable to obtain or maintain all required regulatory approvals. If there is a delay in obtaining required regulatory approvals or if TVA fails to obtain or maintain any approvals or to comply with any law, regulation, or order, TVA may have to change how it operates certain assets, may be unable to operate certain assets, or may have to pay fines or penalties if it continues to operate the assets.
TVA is involved in various legal and administrative proceedings whose outcomes may affect TVA's finances and operations.
TVA is involved in various legal and administrative proceedings, and is likely to become involved in additional proceedings in the future in the ordinary course of business, or as a result of, among other things, catastrophic events or environmental conditions at TVA property or areas where TVA has disposed of materials or property. The additional proceedings could involve, among other things, challenges to TVA's CCR facilities and nuisance suits involving TVA's coal-fired plants. Although TVA cannot predict the outcome of the individual matters in which TVA is involved or will become involved, the resolution of these matters could require TVA to make expenditures in excess of established reserves and in amounts that could have a material adverse effect on TVA's cash flows, results of operations, and financial condition. Similarly, resolution of any such proceedings may require TVA to change its business practices or procedures, change how it operates its coal-fired units, reduce emissions to a greater extent than TVA had planned, close existing CCR facilities sooner than planned, build new CCR facilities sooner than planned, build new CCR facilities that were not planned, or even cease operation of some coal-fired units. These events could also have a material adverse effect on TVA's cash flows, results of operations, and financial condition.
TVA is largely restricted to a defined service area.
TVA's ability to expand its customer base is constrained by its inability to pursue new customers outside its service area. Accordingly, reductions in demand have to be offset by such actions as reducing TVA's internal costs or increasing rates. Any failure of such measures to fully offset the reduced demand for power may negatively affect TVA's cash flows, results of operations, and financial condition.
TVA may become subject to additional NERC requirements.
TVA is subject to federal reliability standards that are set forth by NERC and approved by FERC. TVA recognizes that reliability standards and expectations continue to become more complex and stringent for transmission systems. Currently there are approximately 90 mandatory standards subject to enforcement containing approximately 1,300 requirements and sub-requirements that must be met. Complying with these or additional requirements set forth by NERC may require significant capital expenditures and may negatively affect TVA's cash flows, results of operations, and financial condition.
TVA could be divested by the federal government or be required to sell some or all of its assets.
From time to time, presidential administrations have suggested that the federal government should either divest TVA or require TVA to sell some or all of its assets, including its transmission system. Either event could trigger change of control provisions in certain material contracts or covenants in TVA's bond documents that concern the sale or disposal of a substantial portion of TVA's power properties. TVA may, among other things, be required to pay off debt more quickly than anticipated and be unable to access credit facilities. Additionally, the loss of the transmission system could interfere with TVA's operations and require TVA to contract for the transmission of electricity to TVA customers. These factors could negatively affect TVA's operations, change the way it conducts such operations, and increase costs.
OPERATIONAL RISKS
TVA may incur delays and additional costs in its major projects or may be unable to obtain necessary regulatory approval.
Among other projects, TVA is improving the reliability and resiliency of its transmission system, undertaking repairs at certain hydroelectric facilities and dams, and closing some coal-fired plants and their supporting infrastructure. These activities involve risks of overruns in the cost of labor and materials as well as risks of schedule delays, which may result from, among other things, changes in laws or regulations, lack of productivity, human error, and the failure to schedule activities properly. In addition, if TVA does not or cannot obtain the necessary regulatory approvals or licenses, is otherwise unable to complete the development or construction of a facility, decides to cancel construction of
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a facility, incurs delays or cost overruns in connection with constructing a facility, or is required to change how it will conduct construction, repair, or closure activities, TVA's cash flows, financial condition, and results of operations could be negatively affected. Further, if projects are not completed according to specifications, TVA may suffer, among other things, delays in receiving licenses, reduced plant efficiency, reduced transmission system integrity and reliability, and higher operating costs.
TVA may not be able to operate one or more of its nuclear power units.
Should issues develop with TVA's nuclear power units that TVA is unable to correct, TVA might voluntarily shut down one or more units or be ordered to do so by the NRC. Returning the unit(s) into operation could be a lengthy and expensive process, or might not be possible depending on circumstances. In either case, TVA's cash flows, results of operations, financial condition, and reputation may be negatively affected.
Operating nuclear units subjects TVA to nuclear risks and may result in significant costs that adversely affect its cash flows, results of operations, and financial condition.
TVA has seven operating nuclear units. Risks associated with these units include the following:
Nuclear Risks. A nuclear incident at one of TVA's facilities could have significant consequences including loss of life, damage to the environment, damage to or loss of the facility, and damage to non-TVA property. Although TVA carries certain types of nuclear insurance, the amount that TVA is required to pay in connection with a nuclear incident could significantly exceed the amount of coverage provided by insurance. 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. Any such nuclear incident could also negatively affect TVA by, among other things, obligating TVA to pay retrospective insurance premiums, reducing the availability and affordability of insurance, increasing the costs of operating nuclear units, or leading to increased regulation or restriction on the construction, operation, and decommissioning of nuclear facilities. Moreover, federal legislation could impose revenue-raising measures on the nuclear industry to pay claims exceeding the limit for a single incident under the Price-Anderson Act. Further, the availability or price of insurance may be impacted by TVA's acts or omissions, such as a failure to properly maintain a facility, or events outside of TVA's control, such as an equipment manufacturer's inability to meet a guideline, specification, or requirement.
Decommissioning Costs. TVA maintains a Nuclear Decommissioning Trust ("NDT") for the purpose of providing funds to decommission its nuclear facilities. The NDT is invested in securities generally designed to achieve a return in line with overall equity and debt market performance. TVA might have to make unplanned contributions to the NDT if, among other things:

• | The value of the investments in the NDT declines significantly or the investments fail to achieve the assumed real rate of return;

• | The decommissioning funding requirements are changed by law or regulation;

• | The assumed real rate of return on plan assets, which is currently five percent, is lowered by the TVA Board or is overly optimistic;

• | The actual costs of decommissioning are more than planned;

• | Changes in technology and experience related to decommissioning cause decommissioning cost estimates to increase significantly;

• | TVA is required to decommission a nuclear plant sooner than it anticipates; or

• | The NRC guidelines for calculating the minimum amount of funds necessary for decommissioning activities are significantly changed.

If TVA makes additional contributions to the NDT, the contributions may negatively affect TVA's cash flows, results of operations, and financial condition.
Increased Regulation. The NRC has broad authority to adopt requirements related to the licensing, operating, and decommissioning of nuclear generation facilities that can result in significant restrictions or requirements on TVA. For example, supplementary NRC rulemaking has been developed to mitigate beyond-design basis flooding
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and seismic events. To comply with existing, new, or modified regulations, TVA may be required to make substantial capital expenditures at its nuclear plants or make substantial contributions to the NDT. In addition, if TVA fails to comply with requirements promulgated by the NRC, the NRC has the authority to impose fines, shut down units, or modify, suspend, or revoke TVA's operating licenses.
Waste Disposal. TVA's nuclear operations produce various types of nuclear waste materials, including spent fuel. TVA has been storing the spent fuel in accordance with NRC regulations in anticipation that a final storage site for all such waste will be developed and put in operation by the U.S. government. If no such site is forthcoming or if no alternative disposal or reuse plan is developed, then TVA might be required to arrange for the safe and permanent disposal of the spent fuel itself. Such a requirement would cause TVA to incur substantial expense, including substantial capital expenditures, and could cause TVA to change how it operates its nuclear plants.
Availability of Components. Nuclear facilities require specialized components and access to intellectual property for operation. As the number of reliable suppliers of such components and access to intellectual property is reduced, the availability of the components and access to the intellectual property will also likely decrease. If TVA is unable to secure either the original components, intellectual property, or replacements approved for use by the NRC, TVA might have to change how it conducts its operations.
TVA's management and operation of CCR facilities exposes it to additional costs and risks.
TVA operates coal-fired units which produce CCR as byproducts of the power production process. The CCR is contained within dedicated facilities operated by TVA. TVA has closed some of these facilities in compliance with state and federal laws and is in the process of closing others. Some facilities are intended to remain open during the life of the associated generation unit. Many of these facilities were constructed prior to the requirement that such facilities be built with liners and thus do not contain such liners. TVA has been ordered by TDEC to undertake investigations at all CCR facilities in Tennessee. TVA has also been involved in litigation related to certain CCR facilities and to resolve one such lawsuit, TVA agreed to remove or reuse some CCR material at Gallatin. TVA could be subject to similar litigation or orders in the future and could be required to restrict or stop the use of some or all CCR facilities or relocate CCR material to lined facilities. Further, TVA has decided to move all CCR material at Allen rather than closing them in place as originally planned. TVA may change its closure plans at other facilities depending on the particular facts of each situation and the completion of any required environmental investigations or studies.
TVA's facilities and operations may be damaged or interfered with by physical attacks, threats, or other interference.
TVA has an extensive generation and transmission system and supporting infrastructure that includes, among other things, TVA's generation facilities and transmission infrastructure such as substations, towers, and control centers. Some of TVA's hydroelectric facilities include navigation locks which are necessary for commerce along the Tennessee River system. TVA also operates flood control dams and supporting infrastructure. Because of TVA's status as a governmental corporation and TVA's role as predominately the sole power provider for its service territory, TVA may be targeted by individuals, groups, or nation states for physical attacks or threats of such attacks. Although TVA's operations are protected by automated monitoring systems, TVA Police and Emergency Management, TVA employees, local law enforcement, or a combination thereof, it may not be possible to effectively deter or prevent attacks. Such attacks could pose health and safety risks, significantly disable or destroy TVA assets, interfere with TVA's operations, result in additional regulatory or security requirements, and negatively affect TVA's cash flows, results of operations, and financial condition.
TVA's facilities and information infrastructure may not operate as planned due to cyber threats to TVA's assets and operations.
TVA's operations are heavily computerized and include assets such as information technology and networking systems. As with all industries, the reliance on computerization and networking makes TVA a target for cyber attacks, and the risk of such attacks may increase as individual devices and equipment become accessible via the internet. TVA has been targeted by cyber attacks in the past and anticipates that it will be targeted in the future. These attacks may have been carried out, or in the future could be carried out, by individuals, groups, or nation states. Although TVA has extensive cyber safeguards and works with industry specialists and relevant governmental authorities to deter, stop, or mitigate cyber attacks, it is possible that these measures might not prevent all attacks. In such a case, a cyber attack could compromise sensitive data, significantly disrupt operations, require additional expenditures for cybersecurity, negatively affect TVA's cash flows, results of operations, financial condition, and reputation, and pose health and safety risks. Additionally, the theft, damage, or improper disclosure of sensitive data may subject TVA to penalties and claims from third parties.
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Cyber attacks on third parties could interfere with or harm TVA.
TVA relies on third parties for various services, including transferring funds to non-TVA entities in the ordinary course of business. As with TVA, these third parties are heavily computerized and use assets such as information technology and networking systems. If these third parties undergo cyber attacks, the services they provide TVA could be disrupted. This disruption could interfere with TVA's abilities to perform its obligations to others or transfer funds or make payments, which in turn could negatively affect TVA's financial condition and reputation. Additionally, the theft, damage, or improper disclosure of sensitive data held by these third parties may subject TVA to further harm.
TVA's assets or their supporting infrastructure may not operate as planned.
Many of TVA's assets, including generation, transmission, navigation, and flood control assets, have been operating for several decades and have been in nearly constant service since they were completed. Additionally, certain of TVA's newer assets utilize advanced technology which could experience technical or operating issues. The failure of TVA's assets or supporting infrastructure, including information technology systems, to perform as planned may cause health, safety, or environmental problems and may even result in events such as the failure of a dam, the inability to maintain a reservoir at the normal or expected level, or an incident at a coal-fired, gas-fired, or nuclear plant or a CCR facility. If these assets or their supporting infrastructure fail to operate as planned, if necessary repairs or upgrades are delayed or cannot be completed as quickly as anticipated, or if necessary spare parts are unavailable, TVA, among other things:

• | May have to invest a significant amount of resources to repair or replace the assets or the supporting infrastructure;

• | May have to remediate collateral damage caused by a failure of the assets or the supporting infrastructure;

• | May not be able to maintain the integrity or reliability of the transmission system at normal levels;

•May have to operate less economical sources of power;

• | May have to purchase replacement power on the open market at prices greater than its generation costs;

• | May be required to invest substantially to meet more stringent reliability standards;

• | May be unable to maintain insurance on affected facilities, or be required to pay higher premiums for coverage, unless necessary repairs or upgrades are made;

• | May be unable to operate the assets for a significant period of time; or

• | May not be able to meet its contractual obligations to deliver power.

Any of these potential outcomes may negatively affect TVA's cash flows, results of operations, financial condition, and reputation.
TVA's safety programs may not prevent accidents that could, among other things, impact TVA's operations or financial condition.
TVA's safety program, no matter how well designed and operated, may not completely prevent accidents. In addition to the potential human cost of accidents, which could include injury to employees or members of the public, significant accidents could impact TVA's ability to carry out operations, cause it to shut down facilities, subject it to additional regulatory scrutiny, expose it to litigation, damage its reputation, interfere with its ability to attract or retain a skilled workforce, or harm its financial condition.
Weather conditions may influence TVA's ability to supply power and its customers' demands for power.
Extreme temperatures may increase the demand for power and require TVA to purchase power at high prices to meet the demand from customers, while unusually mild weather may result in decreased demand for power and lead to reduced electricity sales. Also, in periods of below normal rainfall or drought, TVA's low-cost hydroelectric generation may be reduced, requiring TVA to purchase power or use more costly means of producing power. Additionally, periods of either high or low levels of rainfall may impede river traffic, impacting barge deliveries of critical items such as coal and equipment for power facilities. Furthermore, high river water temperatures in the summer may limit TVA's ability to use water from the Tennessee or Cumberland River systems for cooling at certain of TVA's generating facilities, thereby limiting its ability to operate these generating facilities. This situation would be aggravated during periods of reduced rainfall or drought. If changes in the climate make such shifts in weather more common or extreme, TVA may be required to, among other things, change its generation mix or change how it conducts its operations, which could have a material adverse effect on TVA's cash flows, results of operations, and financial condition.
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Catastrophic events may negatively affect TVA's cash flows, results of operations, and financial condition.
TVA's cash flows, results of operations, and financial condition may be adversely affected, either directly or indirectly, by catastrophic events such as fires, earthquakes, explosions, solar events, electromagnetic pulses ("EMP"), droughts, floods, tornadoes, wars or other casualty events or national emergencies, terrorist activities, pandemics, or other similar destructive or disruptive events. These events, the frequency and severity of which are unpredictable, may, among other things, lead to legislative or regulatory changes that affect the construction, operation, and decommissioning of nuclear units and the storage of spent fuel; limit or disrupt TVA's ability to generate and transmit power; limit or disrupt TVA's ability to provide flood control and river management; reduce the demand for power; disrupt fuel or other supplies; require TVA to produce additional tritium; lead to an economic downturn; require TVA to make substantial capital investments for repairs, improvements, or modifications; and create instability in the financial markets. If public opposition to nuclear power makes operating nuclear plants less feasible as a result of any of these events, TVA may be forced to shut down its nuclear plants. This would make it substantially more difficult for TVA to obtain greater amounts of its power supply from low or zero carbon emitting resources and to replace its generation capacity when faced with retiring or idling certain coal-fired units. Additionally, some studies have predicted that climate change may cause catastrophic events, such as droughts and floods, to occur more frequently in the Tennessee Valley region, which could adversely impact TVA.
TVA's service reliability could be affected by problems at other utilities or at TVA facilities, or by the increase in intermittent sources of power.
TVA's transmission facilities are directly interconnected with the transmission facilities of neighboring utilities and are thus part of the larger interstate power transmission grid. Certain of TVA's generation and transmission assets are critical to maintaining reliability of the transmission system. Additionally, TVA uses certain assets that belong to third parties to transmit power and maintain reliability. Accordingly, problems at other utilities as well as at TVA's facilities may cause interruptions in TVA's service to TVA's customers, increase congestion on the transmission grid, or reduce service reliability. In addition, the increasing contribution of intermittent sources of power, such as wind and solar, may place additional strain on TVA's system as well as on surrounding systems. If TVA suffers a service interruption, increased congestion, or reduced service reliability, TVA's cash flows, results of operations, financial condition, and reputation may be negatively affected.
TVA's supplies of fuel, purchased power, or other critical items may be disrupted or obtained at a higher cost than planned.
TVA purchases coal, uranium, natural gas, fuel oil, and electricity from a number of suppliers. Additionally, TVA contracts for conversion of uranium into nuclear fuel and purchases other items, such as anhydrous ammonia, liquid oxygen, or replacement parts that are critical to the operation of certain generation assets. TVA also purchases power from other power producers when the purchase of such power is appropriate due to economic opportunities or operational concerns. Disruption or price volatility in the acquisition or delivery of fuel, purchased power, contracted services, or other critical supplies may result from a variety of physical and commercial events, political developments, international trade restrictions or tariffs, legal actions, or environmental regulations affecting TVA's suppliers as well as from transportation or transmission constraints. If one of TVA's suppliers fails to perform under the terms of its contract with TVA, TVA might have to purchase replacement fuel, power, or other critical supplies, perhaps at a significantly higher price than TVA is entitled to pay under the contract. In some circumstances, TVA may not be able to recover this difference from the supplier. In addition, any disruption of TVA's supplies could require TVA to operate higher cost generation assets, thereby negatively affecting TVA's cash flows, results of operations, and financial condition. Moreover, if TVA is unable to acquire enough replacement fuel, power, or supplies, or does not have sufficient reserves to offset the loss, TVA may not be able to operate certain assets or provide enough power to meet demand, resulting in power curtailments, brownouts, or even blackouts.
Events that affect the supply or quality of water in the Tennessee River system and Cumberland River system or elsewhere may interfere with TVA's ability to generate power.
An inadequate supply of water in the Tennessee River system and Cumberland River system could negatively impact TVA's cash flows, results of operations, and financial condition by reducing generation not only at TVA's hydroelectric plants but also at its coal-fired and nuclear plants, which depend on water from the river systems near which they are located for cooling and for use in boilers where water is converted into steam to drive turbines. Certain of TVA's gas-fired facilities not located near a river require alternative sources of water, such as from wells or local utility companies. Further, the water must be of a particular quality for use in TVA's equipment. If the available water is not of sufficient quality for TVA's use, then TVA must either treat the water or obtain alternate sources. An inadequate supply of quality water could result, among other things, from periods of low rainfall or drought, the withdrawal of water from the river systems by governmental entities or others, incidents affecting bodies of water not managed by TVA, or supply issues which affect water providers. While TVA manages the Tennessee River and a large portion of its tributary system to provide much of the water necessary for the operation of its power plants, the USACE operates and manages other bodies of water upon which some of TVA's facilities rely. Events at these bodies of water or their associated
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hydroelectric facilities may interfere with the flow of water and may result in TVA's having insufficient water quality to meet the needs of its plants. If TVA has insufficient water supply of the quality necessary to meet the needs of its plants, TVA may be required to treat the water, reduce generation at its affected facilities to levels compatible with the available supply of water, or take additional steps that change how TVA conducts its operations or cause TVA to incur additional expense.
TVA's determination of the appropriate mix of generation assets may change.
TVA has determined that its power generation assets should consist of a mix of nuclear, coal-fired, natural gas-fired, and renewable power sources, including hydroelectric. In making this determination, TVA took various factors into consideration, including the anticipated availability of its nuclear units, the availability of non-nuclear facilities, the forecasted cost of natural gas and coal, the forecasted demand for electricity, and environmental compliance including the expense of adding air pollution controls to its coal-fired units. If any of these assumptions materially change or are impacted by subsequent events, then TVA's generation mix may not address its operational needs in the most efficient manner. Resolving such a situation may require capital expenditures or additional power purchases, and TVA's cash flows, results of operations, financial condition, and reputation may be negatively affected.
FINANCIAL, ECONOMIC, AND MARKET RISKS
TVA's cost management efforts may not be successful.
TVA is continuing to improve operating efficiencies to offset any potential future reductions in power demand and maintain its rates, reputation, cash flows, results of operations, and financial condition. The failure to achieve or maintain cost reductions could adversely affect TVA's rates, reputation, cash flows, results of operations, and financial condition.
TVA may have to make significant contributions in the future to fund its qualified pension plan.
At September 30, 2019, TVA's qualified pension plan had assets of approximately $8.0 billion compared to liabilities of approximately $13.3 billion. The plan is mature with approximately 24,000 retirees and beneficiaries receiving benefits of over $700 million per year. The costs of providing benefits depend upon a number of factors, including, but not limited to, provisions of the plan; changing experience and assumptions related to terminations, retirements, and mortality; rates of increase in compensation levels; rates of return on plan assets; discount rates used in determining future benefit obligations and required funding levels; optional forms of benefit payments selected; future government regulation; and levels of contributions made to the plan.
Although the plan is frozen to new participants, any of these factors or any number of these factors could keep at high levels, or even increase, the costs of providing benefits and require TVA to make contributions to the plan in amounts that significantly exceed TVA's planned contributions. Unfavorable financial market conditions may result in lower expected rates of return on plan assets, loss in value of the investments, and lower discount rates used in determining future benefit obligations. These changes would negatively impact the funded status of the plan. Additional contributions to the plan and absorption of additional costs would negatively affect TVA's cash flows, results of operations, and financial condition.
TVA's debt ceiling could be made more restrictive. Additionally, approaching or reaching TVA's debt ceiling could limit TVA's ability to carry out its business.
The TVA Act provides that TVA can issue Bonds in an amount not to exceed $30.0 billion outstanding at any time. At September 30, 2019, TVA had $21.4 billion of Bonds outstanding (not including 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).
Approaching or reaching the debt ceiling may negatively affect TVA's business by limiting TVA's ability to access capital markets and increasing the amount of debt TVA must service. Also, federal legislation may lower TVA's debt ceiling or broaden the types of financial instruments that are covered by the ceiling. Either of these scenarios may also restrict TVA's ability to raise capital to acquire new power program assets or maintain existing ones, to carry out upgrades or improvements to existing assets or build new ones, to purchase power under long-term power purchase agreements, or to meet regulatory requirements. In addition, approaching or reaching the debt ceiling may lead to increased legislative or regulatory oversight of TVA's activities and could lead to negative rating actions by credit rating agencies.
TVA may be unable to meet its current cash requirements if TVA's access to the debt markets is limited.
TVA uses cash provided by operations together with proceeds from power program financings and other financing arrangements to fund its current cash requirements. It is critical that TVA continues to have access to the debt markets in order to meet its cash requirements. The importance of having access to the debt markets is underscored by the fact
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that TVA, unlike most utilities, relies almost entirely on debt capital since, as a governmental instrumentality, TVA cannot issue equity securities.
TVA's credit ratings may be impacted by congressional actions or by a downgrade of the U.S.'s sovereign credit ratings.
TVA's current credit ratings are not based solely on its underlying business or financial condition but are based to a large extent on the legislation that defines TVA's business structure. Key characteristics of TVA's business defined by legislation include (1) the TVA Board's ratemaking authority, (2) the current competitive environment, which is defined by the fence and the anti-cherrypicking provision, and (3) TVA's status as a corporate agency and instrumentality of the U.S. If Congress takes any action that effectively alters any of these characteristics, TVA's credit ratings could be downgraded.
Although TVA Bonds are not obligations of the U.S., TVA, as a corporate agency and instrumentality of the U.S., may be impacted if the sovereign credit ratings of the U.S. are downgraded. Such a downgrade of the U.S.'s sovereign credit ratings could, among other things, result in a downgrade of TVA's credit rating. Additionally, the economy could be negatively impacted resulting in reduced demand for electricity, an increase in borrowing costs, and an increase in the cost of fuels, supplies, and other materials required for TVA's operations. Additionally, the criteria used by the credit rating agencies to assign ratings could be changed at any time, which could result in changes to TVA's ratings.
TVA, together with owners of TVA securities, may be impacted by downgrades of TVA's credit ratings.
Downgrades of TVA's credit ratings may have material adverse effects on TVA's cash flows, results of operations, and financial condition as well as on investors in TVA securities. Among other things, a downgrade could increase TVA's interest expense by increasing the interest rates that TVA pays on new securities that it issues. Such an increase may reduce the amount of cash available for other purposes, which may result in the need to increase borrowings, to reduce other expenses or capital investments, or to increase power rates. A downgrade may also result in TVA's having to post collateral under certain physical and financial contracts that contain ratings triggers. A downgrade below a contractual threshold may prevent TVA from borrowing under four credit facilities totaling $2.7 billion or posting letters of credit as collateral under these facilities. At September 30, 2019, there were $1.3 billion of letters of credit outstanding under these facilities. If TVA were no longer able to post letters of credit as collateral, TVA would likely have to post cash as collateral, which would negatively affect TVA's liquidity. Further, a downgrade may lower the price of TVA securities in the secondary market, thereby negatively impacting investors who sell TVA securities after the downgrade and diminishing the attractiveness and marketability of TVA securities. The criteria used by credit rating agencies to assign ratings could also be changed at any time, which could result in changes to TVA's ratings.
TVA's assumptions about the future may be inaccurate.
TVA uses certain assumptions in order to develop its plans for the future. Such assumptions include economic forecasts, anticipated energy and commodity prices, cost estimates, construction schedules, power demand forecasts, the appropriate generation mix to meet demand, and potential regulatory environments. Should these assumptions be inaccurate, or be superseded by subsequent events, TVA's plans may not be effective in achieving the intended results, which could negatively affect cash flows, results of operations, and financial condition, as well as TVA's ability to meet electricity demand and the way TVA conducts its business.
Demand for electricity may significantly decline or change, negatively affecting TVA's cash flows, results of operations, and financial condition.
Some of the factors that could reduce or change the demand for electricity include, but are not limited to, the following:
Economic downturns. Renewed economic downturns in TVA's service area or other parts of the U.S. could reduce overall demand for power and thus reduce TVA's power sales and cash flows, especially if TVA's industrial customers, which constitute a material portion of TVA's demand, reduce their operations and thus their consumption of power.
Loss of customers. TVA could lose customers, particularly LPCs, if customers choose another utility to meet some or all of their power needs where available, pursue self-generation to meet some or all of their power needs, or move their operations outside of TVA's service territory. At September 30, 2019, TVA had wholesale power contracts with 154 LPCs. A significant portion of TVA's total operating revenues are concentrated in a small number of these LPCs. The loss of customers could have a material adverse effect on TVA's cash flows, results of operations, or financial condition, and could result in higher rates, especially because of the difficulty in replacing customers on account of the fence. A significant loss of customers could also impact investor confidence, resulting in TVA paying higher rates on its securities.
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Change in demand for electricity generated from renewable sources. TVA has been adapting its generation mix to account for the growing preference for electricity generated by renewable sources, such as solar or wind. If demand by customers for power that is largely or exclusively generated from renewable sources exceeds TVA's ability to produce such power, TVA might have to change how it operates and may incur additional expense in meeting this demand.
Increased utilization of DER. As the amount of DER grows on the TVA system, the need for TVA's traditional generation resources may be reduced, and the ability of the system to reliably and economically operate in conjunction with these DER may become more challenging. If TVA is unable to compensate for the resulting decrease in demand for TVA electricity, TVA's cash flows, results of operations, and financial condition could be negatively impacted, resulting in higher rates and changes to TVA's operations.
Increased energy efficiency and conservation. Increasingly efficient use of energy as well as conservation efforts have reduced the demand for power. Further reductions, if TVA is unable to compensate for them, could negatively affect TVA's cash flows, results of operations, and financial condition and could result in higher rates and changes to TVA's operations, especially if the reductions occur during an economic downturn or a period of slow economic growth.
Changes in technology could require TVA to change how it conducts its operations, affect relationships with customers, or impact its financial condition.
TVA's primary business is to sell power it produces, for the most part, from large facilities such as nuclear power plants, hydroelectric facilities, natural gas-fired facilities, and coal-fired units. TVA sells power to LPCs and directly served customers. Research and development activities are ongoing to improve existing and alternative technologies to produce or store electricity, including large-scale energy storage, gas or wind turbines, fuel cells, microturbines, solar cells, and distributed energy or storage resources. It is possible that advances in these or other alternative technologies could reduce the costs of such production methods to a level that will enable these technologies to compete effectively with traditional power plants such as TVA's. These technologies could be more appealing to customers and could lead them to bring pressure on TVA to modify the power contracts to allow customers to generate some of their own power requirements or purchase power from other suppliers. Other customers might also cease purchasing power from TVA altogether. To the extent that sales to such customers are reduced or eliminated, TVA's cash flows, results of operations, and financial condition could be negatively affected. TVA could also be required to modify how it operates its traditional plants or further modify its generation mix to reduce reliance on these facilities.
Additionally, demand could change in terms of amount or timing as devices and equipment become more connected to the internet and it becomes possible to adjust real-time consumption of power. Such increased control over power consumption could, among other things, affect how TVA operates its facilities or dispatches power, or require TVA to change its pricing structure or rates.
TVA is subject to a variety of market risks that may negatively affect TVA's cash flows, results of operations, and financial condition.
TVA is subject to a variety of market risks, including, but not limited to, commodity price risk, investment price risk, interest rate risk, counterparty credit and performance risk, and currency exchange rate risk.
Commodity Price Risk. TVA's rates may increase if prices of commodities critical to operations, including coal, uranium, natural gas, fuel oil, crude oil, construction materials, or emission allowances, increase.
Investment Price Risk. TVA is exposed to investment price risk in its NDT, Asset Retirement Trust ("ART"), Supplemental Executive Retirement Plan ("SERP"), Deferred Compensation Plan ("DCP"), and pension plan. If the value of the investments held in the NDT or the pension fund either decreases or fails to increase in accordance with assumed rates of return, TVA may be required to make substantial contributions to these funds. In addition, although TVA is not required to make contributions to the ART, it may choose to do so, particularly if TVA's estimates of its non-nuclear asset retirement obligation liabilities increase. TVA may also choose to make contributions to the SERP and DCP from time to time.
Interest Rate Risk. Changes in interest rates may increase the amount of interest that TVA pays on new Bonds that it issues, decrease the return that TVA receives on short-term investments, decrease the value of the investments in the NDT, ART, pension fund, SERP, and DCP, increase the amount of collateral that TVA is required to post in connection with certain of its derivative transactions, and increase the losses on the mark-to-market valuation of certain derivative transactions into which TVA has entered.
Counterparty Credit and Performance Risk. TVA is exposed to the risk that its counterparties will not be able to perform their contractual obligations. If TVA's counterparties fail to perform their obligations, TVA's cash flows,
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results of operations, and financial condition may be adversely affected. In addition, the failure of a counterparty to perform may make it difficult for TVA to perform its obligations, particularly if the counterparty is a supplier of electricity or fuel.
Currency Exchange Rate Risk. Over the next several years, TVA expects to spend a significant amount of capital on various projects. A portion of this amount may be spent on contracts that are denominated in one or more foreign currencies. Additionally, TVA's three issues of Bonds denominated in British pounds sterling are hedged by currency swap agreements. The value of the U.S. dollar compared with other currencies has fluctuated widely in recent years, including fluctuations in the U.S. dollar to British pound sterling exchange rate primarily driven by the "BREXIT" vote for the United Kingdom to leave the European Union. If not effectively managed, foreign currency exposure could negatively impact TVA's counterparty risk, cash flows, results of operations, and financial condition.
Changes in an interest rate benchmark may impact certain TVA swaps and other financial arrangements.
TVA has four "fixed for floating" interest rate swaps related to outstanding Bonds and receives periodic payments under these swaps based on the floating London Interbank Offered Rate ("LIBOR") benchmark rate. TVA may also have additional contracts that could be impacted. LIBOR is expected to be discontinued after 2021. Various alternatives for LIBOR are being evaluated by market participants, with the Secured Overnight Financing Rate being the most widely-adopted alternative thus far. TVA may face risks related to the viability of an alternative benchmark over the remaining terms of its current contracts, or over the terms of any future contracts that rely on the benchmark rate.
TVA's ability to use derivatives to hedge certain risks may be limited.
Under the Dodd-Frank Wall Street Reform and Consumer Protection Act and its implementing regulations, TVA is subject to recordkeeping, reporting, and reconciliation requirements related to its derivative transactions. In addition, depending on how regulatory agencies interpret and implement the provisions of this act, TVA's hedging costs may increase, and TVA may have to post additional collateral and margin in connection with its derivative transactions. These occurrences may, among other things, negatively affect TVA's cash flows and cause TVA to reduce or modify its hedging activities, which could increase the risks to which TVA is exposed.
The market for TVA Bonds might be limited.
Although many TVA Bonds are listed on stock exchanges, there can be no assurances that any market will develop or continue to exist for any Bonds. Additionally, no assurances can be made as to the ability of the holders to sell their Bonds or as to the price at which holders will be able to sell their Bonds. Future trading prices of Bonds will depend on many factors, including prevailing interest rates, the then-current ratings assigned to the Bonds, the amount of Bonds outstanding, the time remaining until the maturity of the Bonds, the redemption features of the Bonds, the market for similar securities, and the level, direction, and volatility of interest rates generally, as well as the liquidity of the markets for those securities.
If a particular series of Bonds is offered through underwriters, those underwriters may attempt to make a market in the Bonds. Dealers other than underwriters may also make a market in TVA Bonds. However, the underwriters and dealers are not obligated to make a market in any TVA Bonds and may terminate any market-making activities at any time without notice.
Further, certain investors use the environmental impact or sustainability of an industry as a criteria for deciding whether to invest in that industry. TVA's use of fossil fuels or nuclear power could lead such investors to not purchase TVA Bonds.
In addition, legal limitations may affect the ability of banks and others to invest in Bonds. For example, national banks may purchase TVA Bonds for their own accounts in an amount not to exceed 10 percent of unimpaired capital and surplus. Also, TVA Bonds are "obligations of a corporation which is an instrumentality of the United States" within the meaning of Section 7701(a)(19)(C)(ii) of the Internal Revenue Code for purposes of the 60 percent of assets limitation applicable to U.S. building and loan associations.
TVA may be unable to use regulatory accounting for some or all costs.
TVA uses regulatory accounting to defer certain costs. To qualify for regulatory accounting, costs must meet certain accounting criteria and be approved for regulatory accounting treatment by the TVA Board in its capacity as TVA's regulator. If costs do not meet, or cease to meet, these criteria, or if the TVA Board disallows the treatment or ceases to be TVA's sole regulator in such areas, TVA may not be able to defer those costs. Such an inability to defer costs would likely have a substantial impact on TVA's financial condition and results of operations and could impact the timing and amounts of TVA's rate recovery. For a discussion of regulatory accounting, see Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Policies and Estimates.
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TVA's financial control system cannot guarantee that all control issues and instances of fraud or errors will be detected.
No financial control system, no matter how well designed and operated, can provide absolute assurance that the objectives of the control system are met, and no evaluation of financial controls can provide absolute assurance that all control issues and instances of fraud or errors can be detected. The design of any system of financial controls is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions, regardless of how remote.
Payment of principal and interest on TVA securities is not guaranteed by the U.S.
Although TVA is a corporate agency and instrumentality of the U.S. government, TVA securities are not backed by the full faith and credit of the U.S. Principal and interest on TVA securities are payable solely from TVA's net power proceeds. Net power proceeds are the remainder of TVA's gross power revenues after deducting the costs of operating, maintaining, and administering its power properties and payments to states and counties in lieu of taxes, 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. If TVA were to experience extreme financial difficulty and were unable to make payments of principal or interest on its Bonds, the federal government would not be legally obligated to prevent TVA from defaulting on its obligations. An inability to pay some or all of the principal or interest owed on a TVA security would likely have a negative impact on TVA's financial condition, reputation, and relationship with the investment community, and could result in cross-defaults in other financial arrangements.
GENERAL BUSINESS RISKS
TVA may not be able to implement its business strategy successfully.
TVA's financial condition and results of operations are largely dependent on the extent to which it can implement its business strategy successfully. TVA's strategy includes maintaining low rates, aligning operations and maintenance spending with revenues, effectively maintaining low rates, being responsible stewards, living with its means, meeting reliability expectations and providing a balanced portfolio, and continuously improving, empowering, and engaging its employees. This strategy is subject to business, economic, and competitive uncertainties and contingencies, many of which are beyond TVA's control. If TVA is unable to successfully implement its business strategy, TVA's financial condition and results of operations could be negatively affected.
TVA's organizational structure may not adequately support TVA's anticipated business needs or enable it to meet the needs of its current or potential customers.
TVA has been modifying its organizational structure to better adapt to the forecasted economic environment. If TVA's assumptions about either its forecasts or the proper internal structure of the company to meet the expected environment are inaccurate or if this structure does not adequately support TVA's needs, TVA could face operational or financial challenges that could adversely affect TVA's cash flows, results of operations, and financial condition as well as TVA's ability to attract or retain a skilled workforce and to meet the needs of its current or potential customers.
TVA may have difficulty in adapting its business model to changes in the utility industry and customer preferences.
The traditional business model for power production, selling power from centrally located plants, is facing pressure from a variety of sources, including the potential for self-generation by current or potential customers, new technologies such as energy storage, and increased energy efficiency. These pressures may reduce the demand for TVA power. If TVA does not or cannot adapt to this pressure by adequately changing its business model, TVA's financial condition and results of operations could be negatively affected.
TVA's quasi-governmental status may interfere in its ability to quickly respond to the needs of its current or potential customers or to act solely in the interest of its ratepayers.
As a quasi-governmental entity, TVA has certain legal requirements that prevent it from responding as quickly to potential changes in the market or requests from current or potential customers as might be desired or in comparison to other utilities. For example, TVA is required to comply with the National Environmental Policy Act ("NEPA"), which requires environmental reviews to be performed in connection with certain projects. The delay in responding to requests could damage relationships with current customers, deter potential customers from moving into TVA's service territory, or damage TVA's reputation.
In addition, TVA's nature as a quasi-governmental entity imposes additional pressures that most companies do not face, such as the requirement to support economic development and promote recreational opportunities. TVA must balance
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these obligations with the requirement to provide power at the least system cost. If TVA does not adequately communicate how it fulfills its various missions and the value it provides, its reputation may be harmed, which may result in political pressure to change its nature or operations as well as in the loss of public support.
TVA's reputation may be negatively impacted.
As with any company, TVA's reputation is a vital element of its ability to effectively conduct its business. TVA's reputation could be harmed by a variety of factors, including the failure of a generating asset or supporting infrastructure, failure to effectively manage land and other natural resources entrusted to TVA, real or perceived violations of environmental regulations, real or perceived issues with TVA's safety culture or work environment, significant delays in construction projects, acts or omissions of TVA management, acts or omissions of a contractor or other third party working with or for TVA, the perception of such acts or omissions, measures taken to offset reductions in demand, or a significant dispute with one of TVA's customers. Any deterioration in TVA's reputation may harm TVA's relationships with its customers and stakeholders, may increase TVA's cost of doing business, may interfere with its ability to attract and retain a skilled workforce, and may potentially lead to the enactment of new laws and regulations, or the modification of existing laws and regulations, that negatively affect the way TVA conducts its business.
Failure to attract and retain an appropriately qualified workforce may negatively affect TVA's results of operations.
TVA's business depends on its ability to recruit and retain key executive officers as well as skilled professional and technical employees. The inability to attract and retain an appropriately qualified workforce could adversely affect TVA's ability to, among other things, operate and maintain generation and transmission facilities, complete large construction projects, and successfully implement its continuous improvement initiatives.
Loss of a quorum of the TVA Board could limit TVA's ability to adapt to meet changing business conditions.
Under the TVA Act, a quorum of the TVA Board is five members. Becoming a member of the TVA Board requires confirmation by the U.S. Senate following appointment by the President. Further, the TVA Board members may not continue in office indefinitely until a successor is appointed. As a result, a delay in the appointment or confirmation of directors can threaten the TVA Board's quorum. The TVA Board is responsible for, among other things, establishing the rates TVA charges for power as well as TVA's long-term objectives, policies, and plans. Accordingly, loss of a quorum for an extended period of time would impair TVA's ability to change rates and to modify these objectives, policies, and plans. Such an impairment would likely have a negative impact on TVA's ability to respond to significant changes in technology, the regulatory environment, or the industry overall and, in turn, negatively affect TVA's cash flows, results of operations, and financial condition.
Changes in the membership of the TVA Board and TVA senior management could impact how TVA operates.
The TVA Board is comprised of up to nine part-time members serving staggered, five-year terms. One to two Board members' terms typically expire each year. In addition, there is always the possibility that one or more members of TVA's senior management may retire or otherwise leave TVA. The individuals filling either the TVA Board or senior management positions may wish to change how TVA operates in whole or in part. If the changes are not successful or TVA is not able to adapt properly to such changes, TVA's financial condition, results of operations, reputation, and relationship with customers could be negatively affected.
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ITEM 1B. UNRESOLVED STAFF COMMENTS
Not applicable.
ITEM 2. PROPERTIES
TVA holds personal property in its own name but holds real property as agent for the U.S. TVA may acquire real property as an agent of the U.S. by negotiated purchase or by eminent domain.
Generating Properties
At September 30, 2019, TVA-operated generating assets consisted of seven nuclear units, 26 active coal-fired units, 86 simple-cycle units, 14 combined-cycle power blocks, 113 conventional hydroelectric units, four pumped-storage units, five diesel generator units, and 14 solar sites. As of September 30, 2019, 16 of the simple-cycle combustion turbine units and four of the combined-cycle power blocks were leased to special purpose entities ("SPEs") and leased back to TVA under long-term leases. See Note 13 — Debt and Other Obligations — Lease/Leasebacks. In addition, TVA is leasing the three Caledonia combined-cycle power blocks under a long-term lease. For a discussion of these assets, see Item 1, Business — Power Supply and Load Management Resources.
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Net Capability
The following table summarizes TVA's summer net capability in MW at September 30, 2019:

SUMMER NET CAPABILITY(1) At September 30, 2019
Source of Capability | Location |  | Number of Units |  | Summer Net Capability (MW) |  | Date First Unit Placed in Service (CY) |  | Date Last Unit Placed in Service (CY)
TVA-Operated Generating Facilities |  |  |  |  |  |  |  |  |  |  |
Nuclear |  |  |  |  |  |  |  |  |  |  |  |  |
Browns Ferry(2) | Alabama |  | 3 |  |  | 3,309 |  |  | 1974 |  |  | 1977 |
Sequoyah | Tennessee |  | 2 |  |  | 2,292 |  |  | 1981 |  |  | 1982 |
Watts Bar | Tennessee |  | 2 |  |  | 2,321 |  |  | 1996 |  |  | 2016 |
Total Nuclear |  |  | 7 |  |  | 7,922 |  |  |  |  |  |  |
Coal-Fired |  |  |  |  |  |  |  |  |  |  |
Bull Run | Tennessee |  | 1 |  |  | 865 |  |  | 1967 |  |  | 1967 |
Cumberland | Tennessee |  | 2 |  |  | 2,470 |  |  | 1973 |  |  | 1973 |
Gallatin | Tennessee |  | 4 |  |  | 976 |  |  | 1956 |  |  | 1959 |
Kingston | Tennessee |  | 9 |  |  | 1,398 |  |  | 1954 |  |  | 1955 |
Paradise | Kentucky |  | 1 |  |  | 971 |  |  | 1963 |  |  | 1970 |
Shawnee | Kentucky |  | 9 |  |  | 1,206 |  |  | 1953 |  |  | 1955 |
Total Coal-Fired |  |  | 26 |  | 7,886 |  |  |  |  |  |  |
Natural Gas and/or Oil-Fired(3)(4) |  |  |  |  |  |  |  |  |  |  |  |  |
Simple-Cycle Combustion Turbine |  |  |  |  |  |  |  |  |
Allen | Tennessee |  | 20 |  |  | 456 |  |  | 1971 |  |  | 1972 |
Brownsville | Tennessee |  | 4 |  |  | 468 |  |  | 1999 |  |  | 1999 |
Colbert | Alabama |  | 8 |  |  | 392 |  |  | 1972 |  |  | 1972 |
Gallatin | Tennessee |  | 8 |  |  | 642 |  |  | 1975 |  |  | 2000 |
Gleason | Tennessee |  | 3 |  |  | 500 |  |  | 2000 |  |  | 2000 |
Johnsonville | Tennessee |  | 19 |  |  | 1,189 |  |  | 1975 |  |  | 2000 |
Kemper | Mississippi |  | 4 |  |  | 348 |  |  | 2002 |  |  | 2002 |
Lagoon Creek | Tennessee |  | 12 |  |  | 1,048 |  |  | 2001 |  |  | 2002 |
Marshall County | Kentucky |  | 8 |  |  | 608 |  |  | 2002 |  |  | 2002 |
Subtotal Simple-Cycle Combustion Turbine |  |  | 86 |  |  | 5,651 |  |  |  |  |  |  |
Combined-Cycle Combustion Turbine |  |  |  |  |  |  |  |  |
Ackerman(5) | Mississippi |  | 1 |  |  | 713 |  |  | 2007 |  |  | 2007 |
Allen(6) | Tennessee |  | 1 |  |  | 1,106 |  |  | 2018 |  |  | 2018 |
Caledonia(7) | Mississippi |  | 3 |  |  | 765 |  |  | 2003 |  |  | 2003 |
John Sevier(8) | Tennessee |  | 1 |  |  | 871 |  |  | 2012 |  |  | 2012 |
Lagoon Creek(9) | Tennessee |  | 1 |  |  | 525 |  |  | 2010 |  |  | 2010 |
Magnolia | Mississippi |  | 3 |  |  | 918 |  |  | 2003 |  |  | 2003 |
Paradise(10) | Kentucky |  | 1 |  |  | 1,100 |  |  | 2017 |  |  | 2017 |
Southaven | Mississippi |  | 3 |  |  | 780 |  |  | 2003 |  |  | 2003 |
Subtotal Combined-Cycle Combustion Turbine |  | 14 |  |  | 6,778 |  |  |  |  |
Co-Generation |  |  |  |  |  |  |  |  |
Johnsonville | Tennessee |  | 1 |  |  | 80 |  |  | 1975 |  |  | 2000 |
Total Natural Gas and/or Oil-Fired |  |  | 101 |  |  | 12,509 |  |  |  |  |
Hydroelectric |  |  |  |  |  |  |  |  |  |  |  |  |
Conventional Plants | Alabama |  | 36 |  |  | 1,176 |  |  | 1925 |  |  | 1962 |
| Georgia |  | 2 |  |  | 35 |  |  | 1931 |  |  | 1956 |
| Kentucky |  | 5 |  |  | 223 |  |  | 1944 |  |  | 1948 |
| North Carolina |  | 6 |  |  | 492 |  |  | 1940 |  |  | 1956 |
| Tennessee |  | 64 |  |  | 1,858 |  |  | 1912 |  |  | 1972 |
Pumped-Storage(11) | Tennessee |  | 4 |  |  | 1,616 |  |  | 1978 |  |  | 1979 |
Total Hydroelectric |  |  | 117 |  |  | 5,400 |  |  |  |  |  |  |
Diesel Generator |  |  |  |  |  |  |  |  |  |  |  |  |
Meridian | Mississippi |  | 5 |  |  | 9 |  |  | 1998 |  |  | 1998 |
TVA Non-hydro Renewable Resources(12) |  |  |  |  |  | 1 |  |  |  |  |  |  |
Total TVA-Operated Generating Facilities |  |  |  |  | 33,727 |  |  |  |  |  |  |
Contract Renewable Resources(13) |  |  |  |  |  | 389 |  |  |  |  |  |  |
Power Purchase and Other Agreements(14) |  |  |  |  |  | 3,616 |  |  |  |  |  |  |
Total Summer Net Capability |  |  |  |  |  | 37,732 |  |  |  |  |  |

Notes
(1) Net capability is defined as the ability of an electric system, generating unit, or other system component to carry or generate power for a specified time period
43

and does not include operational limitations such as derates.
(2) The summer net capability for Browns Ferry excludes the impact of the EPU project. The generating capability is expected to increase by an estimated
465 MW after sufficient run time to validate the new capacity.
(3) See Generating Properties above for a discussion of TVA-operated natural gas and/or oil-fired facilities subject to leaseback and long-term lease arrangements.
(4) Peak firing of simple-cycle combustion turbine units accounts for 326 MW of short-term capability.
(5) Ackerman Combined Cycle Facility is a single steam cycle unit driven by two gas turbines (2x1 configuration).
(6) Allen Combined Cycle Facility is a single steam cycle unit driven by two gas turbines (2x1 configuration).
(7) Caledonia Combined Cycle Plant is currently a leased facility operated by TVA.
(8) John Sevier Combined Cycle Facility is a single steam cycle unit driven by three gas turbines (3x1 configuration).
(9) Lagoon Creek Combined Cycle Facility is a single steam cycle unit driven by two gas turbines (2x1 configuration).
(10) Paradise Combined Cycle Facility is a single steam cycle unit driven by three gas turbines (3x1 configuration).
(11) See Item 1, Business — Power Supply and Load Management Resources — Hiwassee Hydro Unit 2 for a discussion of Hiwassee Hydro Unit 2.
(12) TVA owns 1 MW of solar installations at 14 sites.
(13) Contract Renewable Resources include capability from various renewable energy programs established by TVA to encourage the development of solar, wind, biomass, and low-impact hydroelectric generation systems across the Tennessee Valley.
(14) Power Purchase and Other Agreements includes renewable resources. See Item 1, Business — Power Supply and Load Management Resources — Purchased Power and Other Agreements for information on renewable energy power purchase contracts.
Transmission Properties
TVA's transmission system interconnects with systems of surrounding utilities and consisted primarily of the following assets at September 30, 2019:

• | Approximately 2,500 circuit miles of 500 kilovolt, 11,700 circuit miles of 161 kilovolt, 2,000 circuit miles of other voltage transmission lines, and 3,500 miles of fiber optic lines;

• | 510 transmission substations, power switchyards, and switching stations; and

• | 1,314 customer connection points (customer, generation, and interconnection).

At September 30, 2019, certain qualified technological equipment and other software related to TVA's transmission system were leased to private entities and leased back to TVA under long-term leases. See Note 13 — Debt and Other Obligations — Lease/Leasebacks.
Natural Resource Stewardship Properties
TVA operates and maintains 49 dams and manages the following natural resource stewardship properties:

• | Approximately 11,000 miles of reservoir shoreline;

• | Approximately 293,000 acres of reservoir land;

• | Approximately 650,000 surface acres of reservoir water; and

• | Approximately 80 public recreation areas throughout the Tennessee Valley, including campgrounds, day-use areas, and boat launching ramps.

Additionally, TVA manages over 170 agreements for commercial recreation (such as campgrounds and marinas).
As part of its stewardship responsibilities, TVA approval is required to be obtained before any obstruction affecting navigation, flood control, or public lands can be constructed in or along the Tennessee River and its tributaries.
Buildings
TVA has a variety of buildings and structures located throughout its service area including generation and transmission facilities, corporate offices, customer service centers, power service centers, warehouses, visitor centers, and crew quarters. Two significant buildings are its Knoxville Office Complex ("KOC") and the Chattanooga Office Complex in Tennessee. In 2013, TVA initiated a study of its real estate portfolio for the purpose of reducing cost, right-sizing the portfolio, and aligning its real estate with TVA's strategic direction over the next 10 to 20 years. As part of this effort, TVA completed a comprehensive assessment of its real estate holdings in the Knoxville region in 2016. For a discussion of these real estate holdings, see Disposal of Property — Knoxville Property below.
Disposal of Property
TVA has broad authority to dispose of personal property but only limited authority to dispose of real property. TVA's primary, but not exclusive, authority to dispose of real property is briefly described below:

• | TVA has authority to dispose of surplus real property at a public auction;

• | TVA may dispose of real property for certain specified purposes, including providing replacement lands for certain entities whose lands were flooded or destroyed by dam or reservoir construction, providing real property for recreational use, and granting easements and rights-of-way upon which are located transmission or distribution lines;

• | TVA can dispose of real property in connection with the construction of generating plants or other facilities under certain circumstances; and

44

• | TVA has authority to grant easements for rights-of-way and other purposes.

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") prohibits TVA from mortgaging any part of its power properties and from disposing of all or any substantial portion of these properties unless TVA provides for a continuance of the interest, principal, and sinking fund payments due and to become due on all outstanding Bonds, or for the retirement of such Bonds.
Bellefonte Nuclear Plant. On November 14, 2016, following a public auction, TVA entered into a contract to sell substantially all of the Bellefonte site to Nuclear Development, LLC, for $111 million. Nuclear Development, LLC, paid TVA $22 million on November 14, 2016, with the remaining $89 million due at closing. Nuclear Development, LLC, had up to two years from November 14, 2016, to close on the property, and TVA agreed to maintain the site until closing. Nuclear Development, LLC, requested and was granted an extension of the initial closing date to November 30, 2018. Nuclear Development, LLC, failed to obtain NRC approval of the transfer of the Bellefonte nuclear licenses. TVA determined that the Atomic Energy Act required that this approval be obtained before closing. TVA declined to provide a second extension of the purchase agreement. On November 30, 2018, Nuclear Development, LLC, filed suit against TVA in the United States District Court for the Northern District of Alabama. See Note 22 — Commitments and Contingencies — Legal Proceedings for a discussion of the lawsuit filed by Nuclear Development, LLC.
Knoxville Property. In 2016, TVA completed a comprehensive assessment of its real estate holdings in the Knoxville, Tennessee region including the KOC and adjacent Summer Place Complex ("SPC"). As a result of this study and a subsequent environmental assessment in 2017, TVA is in the process of consolidating its Knoxville area employees into the West Tower of the KOC or a centralized field office in Norris, Tennessee. As part of this consolidation effort, TVA may convey the SPC and the majority of the East Tower of the KOC.
ITEM 3. 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 catastrophic events or otherwise. While the outcome of the Legal Proceedings to which TVA is a party cannot be predicted with certainty, any adverse outcome to a Legal Proceeding involving TVA may have a material adverse effect on TVA's cash flows, results of operations, and financial condition. For a discussion of Legal Proceedings involving TVA, see Note 22 — Commitments and Contingencies — Legal Proceedings, which discussions are incorporated by reference into this Item 3.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
45

PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Not applicable.
ITEM 6. SELECTED FINANCIAL DATA
The following selected financial data for the years 2015 through 2019 should be read in conjunction with the audited financial statements and notes thereto (collectively, the "Consolidated Financial Statements") presented in Item 8, Financial Statements and Supplementary Data. Certain reclassifications have been made to the 2015, 2016, and 2017 financial statement presentations to conform to the 2018 and 2019 presentations.

Selected Financial Data(1)(2) For the years ended, or at, September 30 (dollars in millions)
| 2019 |  | 2018 |  | 2017 |  | 2016 |  | 2015
Sales (millions of kWh) | 158,443 |  |  | 160,338 |  |  | 152,362 |  |  | 155,855 |  |  | 158,163 |
Peak load (MW)(3) | 29,569 |  |  | 32,509 |  |  | 29,899 |  |  | 29,824 |  |  | 32,751 |
Operating revenues | $ | 11,318 |  |  | $ | 11,233 |  |  | $ | 10,739 |  |  | $ | 10,616 |  |  | $ | 11,003 |
Net income | $ | 1,417 |  |  | $ | 1,119 |  |  | $ | 685 |  |  | $ | 1,233 |  |  | $ | 1,111 |
Total assets | $ | 50,467 |  |  | $ | 48,667 |  |  | $ | 50,017 |  |  | $ | 50,494 |  |  | $ | 48,745 |
Financial obligations |  |  |  |  |  |  |  |  |  |  |  |  |  |
Long-term debt, net(4) |  |  |  |  |  |  |  |  |
Long-term power bonds, net | $ | 19,094 |  |  | $ | 20,157 |  |  | $ | 20,205 |  |  | $ | 20,901 |  |  | $ | 22,617 |
Long-term debt of variable interest entities, net | 1,089 |  |  | 1,127 |  |  | 1,164 |  |  | 1,199 |  |  | 1,233 |
Long-term notes payable | — |  |  | 23 |  |  | 69 |  |  | 48 |  |  | — |
Total long-term debt, net | $ | 20,183 |  |  | $ | 21,307 |  |  | $ | 21,438 |  |  | $ | 22,148 |  |  | $ | 23,850 |
Current debt, net(4) |  |  |  |  |  |  |  |  |
Short-term debt, net | $ | 922 |  |  | $ | 1,216 |  |  | $ | 1,998 |  |  | $ | 1,407 |  |  | $ | 1,034 |
Current maturities of power bonds | 1,030 |  |  | 1,032 |  |  | 1,728 |  |  | 1,555 |  |  | 32 |
Current maturities of long-term debt of variable interest entities | 39 |  |  | 38 |  |  | 36 |  |  | 35 |  |  | 33 |
Current maturities of notes payable | 23 |  |  | 46 |  |  | 53 |  |  | 27 |  |  | — |
Total current debt, net | $ | 2,014 |  |  | $ | 2,332 |  |  | $ | 3,815 |  |  | $ | 3,024 |  |  | $ | 1,099 |
Total debt(4) | $ | 22,197 |  |  | $ | 23,639 |  |  | $ | 25,253 |  |  | $ | 25,172 |  |  | $ | 24,949 |
Capital leases(5) | $ | 187 |  |  | $ | 182 |  |  | $ | 187 |  |  | $ | 181 |  |  | $ | 105 |
Leaseback obligations | $ | 263 |  |  | $ | 301 |  |  | $ | 339 |  |  | $ | 467 |  |  | $ | 616 |

Notes
(1) See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations for a description of certain items in 2018, 2017, and 2016 affecting results in those years.
(2) See Item 1A, Risk Factors and Note 22 — Commitments and Contingencies for a discussion of risks and contingencies that could affect TVA's future financial results.
(3) TVA met an all-time summer peak demand of 33,482 megawatts ("MW") on August 16, 2007, at 102 degrees Fahrenheit and an all-time winter peak demand of 33,352 MW on January 24, 2014, at 7.3 degrees Fahrenheit.
(4) See Note 10 — Variable Interest Entities and Note 13 — Debt and Other Obligations — Debt Outstanding.
(5) Included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets.
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Dollars in millions except where noted)
The following Management's Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") is intended to help the reader understand the Tennessee Valley Authority ("TVA"), its operations, and its present business environment. The MD&A is provided as a supplement to, and should be read in conjunction with, TVA's consolidated financial statements and the accompanying notes thereto contained in Item 8, Financial Statements and Supplementary Data of this Annual Report on Form 10-K for the fiscal year ended September 30, 2019 (the "Annual Report"). The MD&A includes the following sections:

• | Business and Mission — a general description of TVA's business, objectives, strategic priorities, and core capabilities;

• | Executive Overview — a general overview of TVA's activities and results of operations for 2019;

• | Results of Operations — an analysis of TVA's consolidated results of operations for the three years presented in its consolidated financial statements;

• | Liquidity and Capital Resources — an analysis of cash flows, a description of aggregate contractual obligations, and an overview of financial position;

• | Key Initiatives and Challenges — an overview of current and future initiatives and challenges facing TVA;

• | Critical Accounting Policies and Estimates — a summary of accounting policies that require critical judgments and estimates;

• | Fair Value Measurements — a description of TVA's investments and derivative instruments and valuation considerations;

• | Legislative and Regulatory Matters — a summary of laws and regulations that may impact TVA; and

• | Risk Management Activities — a description of TVA's risk governance and exposure to various market risks.

Business and Mission
Business
TVA operates the nation's largest public power system. At September 30, 2019, TVA provided electricity to approximately 49 large industrial customers, seven federal agency customers, and 154 local power company customers ("LPCs") that serve nearly 10 million people in parts of seven southeastern states. TVA generates nearly all of its revenues from the sale of electricity, and in 2019 revenues from the sale of electricity totaled $11.2 billion. As a wholly-owned agency and instrumentality of the United States ("U.S."), however, TVA differs from other electric utilities in a number of ways:

• | TVA is a government corporation.

• | The area in which TVA sells power is limited by the Tennessee Valley Authority Act of 1933 (the "TVA Act") under a provision known as the "fence"; however, another provision of federal law known as the "anti-cherrypicking" provision generally protects TVA from being forced to provide access to its transmission lines to others for the purpose of delivering power to customers within substantially all of TVA's defined service area.

• | The rates TVA charges for power are set solely by the TVA Board of Directors (the "TVA Board") and are not set or reviewed by another entity, such as a public utility commission. In setting rates, however, 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 be sold at rates as low as feasible.

• | TVA is not authorized to raise capital by issuing equity securities. TVA relies primarily on cash from operations and proceeds from power program borrowings to fund its operations and is authorized by the TVA Act to issue bonds, notes, or other evidences of indebtedness (collectively, "Bonds") in an amount not to exceed $30.0 billion outstanding at any given time. Although TVA's operations were originally funded primarily with appropriations from Congress, TVA has not received any appropriations from Congress for any activities since 1999 and, as directed by Congress, has funded essential stewardship activities primarily with power revenues.

47

TVA's Mission of Service
TVA was built for the people, created by federal legislation, and charged with a unique mission - to improve the quality of life in a seven-state region through the integrated management of the region's resources. TVA's mission focuses on three key areas:

ENERGY | ENVIRONMENT | ECONOMIC DEVELOPMENT

• | Energy — Delivering affordable, reliable power;

• | Environment — Caring for the region's natural resources; and

• | Economic Development — Creating sustainable economic growth.

While TVA's mission has not changed since it was established in 1933, the climate in which TVA operates continues to evolve. The business and economic environment has become more challenging due to economic conditions; tougher environmental standards; and the need to diversify its power supply and adapt to changing customer usage behaviors, new technologies, and emerging, non-traditional competition. To continue its mission of service, TVA must realize four strategic imperatives through people performance excellence:

• | Rates — Maintain low rates;

• | Stewardship — Be responsible stewards;

• | Debt — Live within its means;

• | Asset Portfolio — Meet reliability expectations and provide a balanced portfolio; and

• | People Performance Excellence — Continuously improve, empower, and engage employees.

TVA's mission sets the stage for its strategic planning process that includes strategic objectives, initiatives, and scorecards for performance designed to provide clear direction for improving TVA's core business.
48

Linking the Mission to Performance
TVA has formulated key performance measures to support its strategic imperatives. The intent of these measures is to align employees to TVA's mission by focusing its collective efforts on operational excellence, fiscal responsibility, and economic development and environmental stewardship. The measures are designed to promote teamwork, encourage high performance behaviors, and motivate TVA employees to achieve goals aligned with TVA's mission and values. The 2019 corporate results compared with targets for these key measures are reflected in the chart below. See Item 11, Executive Compensation — Compensation Discussion and Analysis for information regarding how the measures are calculated.

Corporate Measure | Weight | Actual | Threshold | Target | Stretch
TVA total spending ($ millions) | 40% | $ | 4,467 |  | $ | 4,862 |  | $ | 4,725 |  | $ | 4,589 |
Load not served (system minutes) | 30% | 3.7 |  | 4.8 |  | 4.0 |  | 3.6 |
Nuclear unit capability factor (UCF) (%) | 15% | 89.8 | % | 89.5 | % | 90.3 | % | 91.1 | %
Combined cycle seasonal equivalent forced outage rate (%) | 10% | 7.5 | % | 3.3 | % | 2.0 | % | 1.5 | %
Coal seasonal equivalent forced outage rate (%) | 5% | 12.7 | % | 13.6 | % | 12.1 | % | 10.8 | %

Executive Overview
TVA's net income for the years ended September 30, 2019 and 2018, was $1.4 billion and $1.1 billion, respectively. As is often the case for electric utilities, weather is a primary driver of TVA's sales. TVA's service territory experienced overall milder than normal weather during 2019, despite record-setting cold weather experienced during November 2018 and record-setting heat during September 2019. This overall milder weather drove lower energy sales. However, revenue from sales of electricity increased $84 million for the year ended September 30, 2019, as compared to the prior year, primarily driven by the base rate adjustment that became effective October 1, 2018.
Fuel and purchased power expense decreased $119 million for the year ended September 30, 2019, as compared to the prior year. This was primarily due to lower energy sales and an increase in hydroelectric generation. Operating and maintenance expense increased $492 million for the year ended September 30, 2019, as compared to the prior year. This increase was primarily driven by accelerated recovery of the regulatory asset for environmental cleanup costs related to the Kingston ash spill in accordance with the TVA Board's ratemaking authority, an increase in project write-offs and materials and supplies inventory reserves and write-offs associated with the anticipated retirement of Paradise Fossil Plant ("Paradise") and Bull Run Fossil Plant ("Bull Run"), and increased outage expense driven by additional planned nuclear outage days.
TVA continues to work with local power company customers ("LPCs") to provide flexibility to meet future changing needs of consumers. During 2019, TVA implemented a change to the structure of its wholesale electric power rates through pricing that better aligns wholesale rates with the underlying cost to serve customers. In addition, the TVA Board approved a 20-year Partnership Agreement option that better aligns the length of LPC contracts with TVA's long-term commitments. The TVA Board also approved a joint project with LPCs to explore options for aggregated procurement of utility-scale and mid-scale renewable generation. Further, TVA issued a request for proposal in April 2019 for up to 200 MW of new renewable energy, in response to customer demand. With these proactive solutions, TVA expects to provide a stable foundation that provides the flexibility to embrace new trends and to continue delivering more innovative energy options.
TVA remains committed to planning its system in a way that ensures evolving resource portfolios remain reliable and provide the most value to all customers. TVA utilizes an Integrated Resource Plan ("IRP") to provide direction on how to best meet future electricity demand considering many views of the future to determine how TVA can continue to provide low-cost, reliable electricity, support environmental stewardship, and spur economic development in the Tennessee Valley over the next 20 years. The 2019 IRP was approved by the TVA Board at its August 2019 meeting.
Additionally, TVA has conducted economic analyses of its generating assets, considering load outlook, economic benefits and costs, performance, and environmental and social impacts. During its February 2019 meeting, the TVA Board approved the retirement of Paradise Unit 3 by December 2020 and Bull Run by December 2023. Subsequent to the Board approval, TVA determined Paradise would not be restarted after January 2020 due to the plant's material condition.
During 2019, TVA completed the final phase of the extended power uprate ("EPU") project at Browns Ferry Nuclear Plant ("Browns Ferry") and is currently finalizing testing and validation. The generating capacity is expected to increase by an estimated 465 MW after sufficient run time to validate the new capacity.
During 2019, TVA continued to achieve 99.999 percent reliability in delivering energy to its customers. TVA's reliability and economic development efforts continued to attract and encourage the expansion of business and industries in the Tennessee Valley, with over $8.9 billion in investments and approximately 66,500 jobs created or retained during the year.
49

Results of Operations
Sales of Electricity
Sales of electricity accounted for nearly all of TVA's operating revenues in 2019, 2018, and 2017. TVA sells power at wholesale rates to LPCs who then resell the power to their customers at retail rates. TVA also sells power to directly served customers, consisting primarily of federal agencies and customers with large or nonstandard loads. In addition, power exceeding the TVA system's needs is sold under exchange power arrangements with certain other power systems.
The following chart compares TVA's sales of electricity for the years ended September 30, 2019, 2018, and 2017:

| Sales of Electricity |
For the years ended September 30
| (millions of kWh) |

Notes
(1) Includes approximately 429 million kilowatt hours ("kWh") of pre-commercial generation at Allen Combined Cycle Plant ("Allen CC"). See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations.
(2) Includes approximately 857 million kWh of pre-commercial generation at Watts Bar Nuclear Plant ("Watts Bar") Unit 2, Paradise Combined Cycle Plant ("Paradise CC"), and Allen CC. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations.
Weather affects both the demand for TVA power and the price for that power. TVA uses degree days to measure the impact of weather on its power operations. Degree days measure the extent to which the TVA system 23-station average temperatures vary from 65 degrees Fahrenheit. During 2019, TVA transitioned degree day calculation methodologies, moving from the average temperatures of the five largest cities in TVA's service area to the average temperatures of 23 stations throughout TVA's service area. This transition provides TVA with increased geographic granularity throughout its service territory and improves modeling accuracy.
2019 Compared to 2018

| Degree Days
| 2019 |  | Normal |  | Percent Variation |  | 2018(1) |  | Normal(1) |  | Percent Variation |  | 2019 |  | 2018(1) |  | Percent Change
Heating Degree Days | 3,219 |  |  | 3,360 |  |  | (4.2 | )% |  | 3,381 |  |  | 3,360 |  |  | 0.6 | % |  | 3,219 |  |  | 3,381 |  |  | (4.8 | )%
Cooling Degree Days | 2,020 |  |  | 1,686 |  |  | 19.8 | % |  | 2,012 |  |  | 1,686 |  |  | 19.3 | % |  | 2,020 |  |  | 2,012 |  |  | 0.4 | %
Total Degree Days | 5,239 |  |  | 5,046 |  |  | 3.8 | % |  | 5,393 |  |  | 5,046 |  |  | 6.9 | % |  | 5,239 |  |  | 5,393 |  |  | (2.9 | )%

Note
(1) The prior period degree day information has been adjusted in order to incorporate a change in TVA's current calculation of this information. Every five years this calculation is updated in order to incorporate the current 15-year period of weather history. The most recent update, to incorporate weather history for CYs 2001-2015, occurred during the first quarter of 2019.
50

Sales of electricity decreased approximately one percent for the year ended September 30, 2019, as compared to the prior year, primarily due to decreased sales volume for LPCs driven predominantly by a five percent decrease in heating degree days. During November 2018, TVA recorded its second highest peak power demand for the month of November at 26,714 MW. During September 2019, TVA experienced nine days with demand over 28,000 MW, breaking TVA's record for the most days in September with demand over 28,000 MW. Further, during September 2019, TVA broke its September 30-day average peak load record with an average peak load of 26,258 MW. Despite this record-setting weather, the TVA service territory experienced overall milder than normal weather in 2019 driven by overall lower than normal heating degree days. Partially offsetting the decreased sales volume for LPCs, sales to industries directly served increased slightly, particularly in the polysilicon sector.
2018 Compared to 2017

| Degree Days
| 2018(1) |  | Normal(1) |  | Percent Variation |  | 2017(1) |  | Normal(1) |  | Percent Variation |  | 2018(1) |  | 2017(1) |  | Percent Change
Heating Degree Days | 3,381 |  |  | 3,360 |  |  | 0.6 | % |  | 2,446 |  |  | 3,360 |  |  | (27.2 | )% |  | 3,381 |  |  | 2,446 |  |  | 38.2 | %
Cooling Degree Days | 2,012 |  |  | 1,686 |  |  | 19.3 | % |  | 1,682 |  |  | 1,686 |  |  | (0.2 | )% |  | 2,012 |  |  | 1,682 |  |  | 19.6 | %
Total Degree Days | 5,393 |  |  | 5,046 |  |  | 6.9 | % |  | 4,128 |  |  | 5,046 |  |  | (18.2 | )% |  | 5,393 |  |  | 4,128 |  |  | 30.6 | %

Note
(1) The prior period degree day information has been adjusted in order to incorporate a change in TVA's current calculation of this information. Every five years this calculation is updated in order to incorporate the current 15-year period of weather history. The most recent update, to incorporate weather history for CYs 2001-2015, occurred during the first quarter of 2019.
Sales of electricity increased approximately five percent for the year ended September 30, 2018, as compared to the prior year, primarily due to increased sales volume for LPCs driven predominantly by a 31 percent increase in total degree days. Colder than normal weather during January 2018 led to TVA setting an all-time record for energy demand in a 24-hour period, as TVA delivered 706 million kWh of energy to the Tennessee Valley. Also in January 2018, TVA set three of its top-12 winter peak demand records. In addition, TVA's service territory experienced overall warmer than normal weather during the third and fourth quarters of 2018. Partially offsetting the increased sales volume for LPCs was a slight decrease in sales to industries directly served, particularly in the pulp and paper and polysilicon sectors.
Financial Results
The following table compares operating results for 2019, 2018, and 2017:

Summary Consolidated Statements of Operations
| 2019 |  | 2018 |  | 2017
Operating revenues | $ | 11,318 |  |  | $ | 11,233 |  |  | $ | 10,739 |
Operating expenses(1) | 8,507 |  |  | 8,665 |  |  | 8,006 |
Operating income | 2,811 |  |  | 2,568 |  |  | 2,733 |
Other income, net | 62 |  |  | 50 |  |  | 56 |
Other net periodic benefit cost(2) | 258 |  |  | 256 |  |  | 758 |
Interest expense, net | 1,198 |  |  | 1,243 |  |  | 1,346 |
Net income | $ | 1,417 |  |  | $ | 1,119 |  |  | $ | 685 |

Note
(1) For the year ended September 30, 2019, TVA recorded $566 million of accelerated depreciation and $170 million of write-offs related to the anticipated retirements of Paradise and Bull Run. See Note 6 — Plant Closures. For the years ended September 30, 2019 and 2018, TVA recorded $266 million and $857 million of accelerated amortization of certain regulatory assets, respectively. See Note 8 — Regulatory Assets and Liabilities.
(2) For the year ended September 30, 2017, TVA made a one-time additional discretionary $500 million contribution to TVA's pension plan.
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Operating Revenues. Operating revenues for the years ended September 30, 2019, 2018, and 2017 consisted of the following:

| Operating Revenues |
For the years ended September 30

Notes
(1) Excludes a contra-revenue amount of approximately $11 million representing revenue capitalized during pre-commercial operations at Allen CC. See Note 1 — Pre-Commercial Plant Operations.
(2) Excludes a contra-revenue amount of approximately $22 million representing revenue capitalized during pre-commercial operations at Watts Bar Unit 2, Paradise CC, and Allen CC. See Note 1 — Pre-Commercial Plant Operations.
TVA's current rate structure provides pricing signals intended to signal higher cost periods to serve its customers and capture a portion of TVA's fixed costs in fixed charges. The structure includes three base revenue components: time of use demand charges, time of use energy charges, and a grid access charge ("GAC"). The demand charges are based upon the customer's peak monthly usage and increase as the peak increases. The energy charges are based on time differentiated kWh used by the customer. Both of these components can be significantly impacted by weather. The GAC, which was implemented in October 2018, captures a portion of fixed costs and will be offset by a corresponding reduction to the energy rates. The GAC will also reduce the impact of weather variability to the overall rate structure. Recognizing the need for flexibility, all LPCs were presented with the option to implement the GAC in October 2018 or defer the implementation until October 2019. Seventy-nine LPCs elected to implement in October 2018, while the remaining 75 implemented the wholesale changes in October 2019.
Additionally, 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. 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, which represents 56 percent of total operating revenues in 2019.
In addition to base revenues, the rate structure also includes a separate fuel rate that includes the costs of natural gas, fuel oil, purchased power, coal, emission allowances, nuclear fuel, and other fuel-related commodities; realized gains and losses on derivatives purchased to hedge the costs of such commodities; and payments to states and counties in lieu of taxes ("tax equivalents") associated with the fuel cost adjustments. See Item 1, Business — Rates — Rate Methodology.
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The changes in revenue components are summarized below:

| 2019 |  | Variance 2019 vs 2018 |  | 2018 |  | Variance 2018 vs 2017 |  | 2017 |
Base revenue |  |  |  |  |  |  |  |  |  |  |
Energy revenue | 5,128 |  |  | (206 | ) |  | 5,334 |  | (1) | 448 |  |  | 4,886 |  | (2)
Demand revenue | 3,609 |  |  | 154 |  |  | 3,455 |  |  | 195 |  |  | 3,260 |  |
Grid access charge | 257 |  |  | 257 |  |  | — |  |  | — |  |  | — |  |
Other charges and credits(3) | (638 | ) |  | 22 |  |  | (660 | ) |  | (13 | ) |  | (647 | ) |
Total base revenue | 8,356 |  |  | 227 |  |  | 8,129 |  |  | 630 |  |  | 7,499 |  |
Fuel cost recovery | 2,799 |  |  | (140 | ) |  | 2,939 |  |  | (142 | ) |  | 3,081 |  |
Off-system sales | 4 |  |  | (3 | ) |  | 7 |  |  | 1 |  |  | 6 |  |
Revenue from sales of electricity | 11,159 |  |  | 84 |  |  | 11,075 |  |  | 489 |  |  | 10,586 |  |
Other revenue | 159 |  |  | 1 |  |  | 158 |  |  | 5 |  |  | 153 |  |
Total operating revenues | $ | 11,318 |  |  | $ | 85 |  |  | $ | 11,233 |  |  | $ | 494 |  |  | $ | 10,739 |  |

Notes
(1) Includes the impact of revenue capitalized during pre-commercial operations of approximately $11 million for the year ended September 30, 2018, at Allen CC. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations.
(2) Includes the impact of revenue capitalized during pre-commercial operations of approximately $22 million for the year ended September 30, 2017, at Watts Bar Unit 2, Paradise CC, and Allen CC. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations.
(3) Includes economic development credits to promote growth in the Tennessee Valley, hydro preference credits for residential customers of LPCs, interruptible credits allowing TVA to reduce industrial customer usage in periods of peak demand to balance system demand, and long-term partnership agreement credits for LPC's that have committed to the 20-year contract with TVA. See Note 17 — Revenue.
2019 Compared to 2018
Operating revenues increased $85 million for the year ended September 30, 2019, as compared to the prior year, primarily due to a $227 million increase in base revenue. The $227 million increase in base revenue was driven by an increase of $318 million attributable to higher effective rates resulting from the base rate adjustment that became effective October 1, 2018, partially offset by a $103 million decrease attributable to lower sales volume. During November 2018, TVA recorded its second highest peak power demand for the month of November at 26,714 MW. During September 2019, TVA experienced nine days with demand over 28,000 MW, breaking TVA's record for the most days in September with demand over 28,000 MW. TVA also broke its September 30-day average peak load record with an average peak load of 26,258 MW. Despite this record-setting weather, the TVA service territory experienced overall milder than normal weather in 2019 driven by overall lower than normal heating degree days. Partially offsetting these increases was a $140 million decrease in fuel cost recovery revenues, driven by a $104 million decrease attributable to lower fuel rates and a $35 million decrease attributable to lower energy sales. The lower fuel rates experienced were primarily driven by lower market prices for natural gas and increased hydroelectric generation.
2018 Compared to 2017
Operating revenues increased $494 million for the year ended September 30, 2018, as compared to the prior year, primarily due to a $630 million increase in base revenue. The $630 million increase in base revenue was driven by an increase of $460 million resulting from higher sales volume during the year ended September 30, 2018, as compared to the prior year. Colder than normal weather during January 2018 led to TVA setting an all-time record for energy demand in a 24-hour period. Also in January 2018, TVA set three of its top-12 winter peak demand records. In addition, TVA's service territory experienced overall warmer than normal weather during the third and fourth quarters of 2018. Further, approximately $159 million of the increase in base revenue was attributable to higher effective rates during the year ended September 30, 2018, as compared to the prior year, resulting from the base rate adjustment that became effective October 1, 2017. The base revenue increase was also due in part to an approximately $11 million decrease in capitalization of revenue resulting from pre-commercial generation during the year ended September 30, 2018, as compared to the prior year. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations. Partially offsetting these increases was a $142 million decrease in fuel cost recovery revenues, driven by a $305 million decrease attributable to lower fuel rates partially offset by a $163 million increase attributable to higher energy sales. The lower fuel rates experienced were primarily driven by lower market prices for natural gas and a change in the mix of generation resources, including more nuclear, natural gas, and hydroelectric generation and less coal-fired generation.
See Sales of Electricity above for further discussion of the change in the volume of sales of electricity and Operating Expenses below for further discussion of the change in fuel expense.
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Operating Expenses. Operating expense components as a percentage of total operating expenses for 2019, 2018, and 2017 consisted of the following:
The following table summarizes TVA's expenses for various fuels for the years indicated:

Fuel Expense for TVA-Owned Facilities(1) For the years ended September 30
| Fuel Expense By Source |  | Cost per kWh(4)
| 2019 |  | 2018 |  | 2017 |  | 2019 |  | 2018 |  | 2017
Coal(2) | $ | 744 |  |  | $ | 847 |  |  | $ | 1,060 |  |  | 2.66 |  |  | 2.68 |  |  | 2.71 |
Natural gas and/or oil-fired(3) | 783 |  |  | 846 |  |  | 706 |  |  | 2.47 |  |  | 2.64 |  |  | 2.78 |
Nuclear fuel | 369 |  |  | 374 |  |  | 334 |  |  | 0.58 |  |  | 0.58 |  |  | 0.57 |
Total fuel | $ | 1,896 |  |  | $ | 2,067 |  |  | $ | 2,100 |  |  | 1.54 |  |  | 1.62 |  |  | 1.70 |

Notes
(1) Excludes effects of the fuel cost adjustment deferrals and amortization on fuel expense in the amounts of $(18) million and $69 million for the years ended September 30, 2018 and 2017, respectively. The effect on fuel expense from the fuel cost adjustment deferrals and amortization was less than $1 million for the year ended September 30, 2019, and therefore is not represented in the table above.
(2) Fuel expense related to oil consumed for startup at coal-fired facilities was $25 million, $21 million, and $18 million for the years ended September 30, 2019, 2018, and 2017, respectively.
(3) Fuel expense related to oil consumed for generation at natural gas and/or oil-fired facilities was $2 million, $8 million, and $2 million for the years ended September 30, 2019, 2018, and 2017, respectively.
(4) Total cost per kWh is based on a weighted average.
The following table shows TVA's generation and purchased power by generating source as a percentage of all electrical power generated and purchased (based on kWh) for the periods indicated:

Power Supply from TVA-Operated Generation Facilities and Purchased Power For the years ended September 30 (millions of kWh)
| 2019 |  | 2018 |  | 2017 |
Coal-fired | 27,934 |  |  | 17 | % |  | 31,471 |  |  | 19 | % |  | 39,019 |  |  | 25 | % |
Nuclear(1) | 63,433 |  |  | 39 | % |  | 64,194 |  |  | 39 | % |  | 58,742 |  |  | 38 | % |
Hydroelectric | 16,058 |  |  | 10 | % |  | 13,736 |  |  | 9 | % |  | 10,967 |  |  | 7 | % |
Natural gas and/or oil-fired(2) | 31,704 |  |  | 20 | % |  | 32,104 |  |  | 20 | % |  | 25,485 |  |  | 16 | % |
Total TVA-operated generation facilities(3) | 139,129 |  |  | 86 | % |  | 141,505 |  |  | 87 | % |  | 134,213 |  |  | 86 | % |
Purchased power (non-renewable)(4) | 14,105 |  |  | 9 | % |  | 14,183 |  |  | 9 | % |  | 13,586 |  |  | 9 | % |
Purchased power (renewable)(5) | 7,840 |  |  | 5 | % |  | 7,245 |  |  | 4 | % |  | 7,127 |  |  | 5 | % |
Total purchased power | 21,945 |  |  | 14 | % |  | 21,428 |  |  | 13 | % |  | 20,713 |  |  | 14 | % |
Total power supply | 161,074 |  |  | 100 | % |  | 162,933 |  |  | 100 | % |  | 154,926 |  |  | 100 | % |

Notes
(1) The nuclear generation amount for the year ended September 30, 2017 includes approximately 495 million kWh of pre-commercial generation at Watts Bar Unit 2. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations.
(2) The natural gas and/or oil-fired generation amount for the years ended September 30, 2018 and 2017, includes approximately 429 million kWh and 362 million kWh, respectively, of pre-commercial generation at Allen CC and Paradise CC. See Note 1 — Summary of Significant Accounting Policies — Pre-Commercial Plant Operations.
(3) Generation from TVA-owned non-hydroelectric renewable resources is less than one percent for all periods shown and therefore is not represented in the table above.
(4) Purchased power (non-renewable) includes generation from Caledonia Combined Cycle Plant ("Caledonia CC"), which is currently a leased facility operated by TVA. Generation from Caledonia CC was 4,181 million kWh, 4,125 million kWh, and 4,276 million kWh for the years ended September 30, 2019, 2018, and 2017, respectively.
(5) Purchased power (renewable) includes power purchased from the following renewable sources: hydroelectric, solar, wind, and cogeneration.
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2019 Compared to 2018

Fuel
Fuel expense decreased $153 million for the year ended September 30, 2019, as compared to the prior year. Lower effective fuel rates contributed $136 million to the decrease resulting from lower market prices for natural gas and increased hydroelectric generation. Lower fuel volume contributed $35 million to the decrease driven by lower sales of electricity. Partially offsetting these decreases was an increase of $18 million driven by variances in fuel rate recovery resulting from the winter peaks experienced in 2018 compared to the overall milder than normal weather in 2019.

Purchased Power
Purchased power expense increased $34 million for the year ended September 30, 2019, as compared to the prior year. This was primarily due to a $23 million increase in the volume of purchased power used to meet first quarter peaks during a period of lower TVA-owned generation resulting from planned outage timing and a $14 million increase in fuel rate recovery resulting from the winter peaks experienced in 2018 compared to the overall milder than normal weather in 2019. Partially offsetting these increases was a decrease of $3 million in the price of purchased power.

Operating and Maintenance
Operating and maintenance expense increased $492 million for the year ended September 30, 2019, as compared to the prior year. This increase was primarily driven by an increase of $266 million due to accelerated recovery of the regulatory asset for environmental cleanup costs related to the Kingston ash spill in accordance with the TVA Board's ratemaking authority and an increase of $170 million related to the announced retirements of Paradise and Bull Run, including $151 million of project write-offs and $19 million of inventory write-offs and reserves. Additionally, an increase in planned nuclear outage days increased outage expense by $39 million.

Depreciation and Amortization
Depreciation and amortization expense decreased by $554 million for the year ended September 30, 2019, as compared to the prior year. This decrease was primarily driven by a decrease of $1.1 billion of prior year amortization of Deferred nuclear generating units and Nuclear training costs regulatory assets due to excess revenues collected in 2018 in accordance with the TVA Board's ratemaking authority and a decrease of $59 million due to the retirements of certain units at Allen Fossil Plant and Johnsonville Fossil Plant. Partially offsetting this decrease was an increase of recognized accelerated depreciation expense of $566 million due to the decision to accelerate the retirement of Paradise and Bull Run and $31 million from new additions to completed Plant.

Tax Equivalents
Tax equivalents expense increased $23 million for the year ended September 30, 2019, as compared to the prior year. This change is primarily driven by an increase in TVA's overall revenue in 2018, which is used as the basis for calculating tax equivalents expense.

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2018 Compared to 2017

Fuel
Fuel expense decreased $120 million for the year ended September 30, 2018, as compared to the prior year. The impact of lower effective fuel rates, driven by lower market prices for natural gas and changes in the mix of generation resources, including more nuclear, natural gas, and hydroelectric generation and less coal-fired generation, contributed $234 million to the decrease. As an indication of the general market direction, the average Henry Hub natural gas spot price for the year ended September 30, 2018, was approximately three percent lower than the price for the prior year. Partially offsetting this decrease was a $114 million increase in fuel expense driven by a five percent increase in generation from TVA-operated resources to meet increased sales during the period.

Purchased Power
Purchased power expense decreased $18 million for the year ended September 30, 2018, as compared to the prior year. This was primarily due to a decrease of $42 million in the price of the purchased power and variances in fuel rate recovery. Partially offsetting these decreases was an increase of $24 million driven by a three percent increase in power purchased to meet increased sales during the period.

Operating and Maintenance
Operating and maintenance expense decreased $6 million for the year ended September 30, 2018, as compared to the prior year. There was a decrease in refueling outage days which reduced outage expense by $35 million, primarily from planned outages. This decrease in operating and maintenance expense was partially offset by an increase of $28 million in inventory write-off expense, as compared to the prior year, primarily related to transitioning from a site-specific inventory management policy to a fleet-wide strategy for each generation type.

Depreciation and Amortization
Depreciation and amortization expense increased by $810 million primarily driven by $857 million of accelerated amortization of the Deferred nuclear generating units and Nuclear training costs regulatory assets due to excess revenues collected in 2018 in accordance with the TVA Board's ratemaking authority. See Note 7. These items were partially offset by a decrease of $100 million in depreciation expense related to the retirement of certain units at Allen Fossil Plant, Paradise Fossil Plant, and Johnsonville Fossil Plant. In addition, there was an increase of approximately $53 million for net additions to completed plant including the completion of Allen CC, which commenced commercial operations in April 2018, and Paradise CC, which commenced commercial operations in April 2017.

Tax Equivalents
Tax equivalents expense decreased $7 million for the year ended September 30, 2018, as compared to the prior year. This change is primarily driven by a decrease in the tax equivalents collected in the fuel rate recovery. The tax equivalents collected in the fuel rate recovery equal five percent of the fuel revenues.

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Interest Expense. Interest expense and interest rates for 2019, 2018, and 2017 were as follows:

Interest Expense and Rates(4) For the years ended September 30
| 2019 |  | Percent Change |  | 2018 |  | Percent Change |  | 2017
Interest expense(1) | $ | 1,198 |  |  | (3.6 | )% |  | $ | 1,243 |  |  | (7.7 | )% |  | $ | 1,346 |
Average blended debt balance(2) | $ | 23,266 |  |  | (6.3 | )% |  | $ | 24,832 |  |  | (1.8 | )% |  | $ | 25,281 |
Average blended interest rate(3) | 4.92 | % |  | 2.3 | % |  | 4.81 | % |  | (5.9 | )% |  | 5.11 | %

Notes
(1) Interest expense includes amortization of debt discounts, issuance, and reacquisition costs, net.
(2) Includes average balances of long-term power bonds, debt of variable interest entities ("VIE"), and discount notes.
(3) Includes interest on long-term power bonds, debt of VIE, and discount notes.
(4) There were no Allowance for Funds Used During Construction ("AFUDC") amounts for the periods shown above.
2019 Compared to 2018
Total interest expense decreased $45 million for the year ended September 30, 2019, as compared to the prior year. This was primarily driven by a decrease of $63 million due to lower average balances on long-term debt and $5 million due to lower average balances on short-term debt. Partially offsetting these decreases was an increase of $7 million due to higher average rates on long-term debt and an increase of $13 million due to higher average rates on short-term debt.
2018 Compared to 2017
Total interest expense decreased $103 million for the year ended September 30, 2018, as compared to the prior year. This was primarily driven by a decrease of $97 million due to lower average balances and rates on long-term debt, partially offset by an increase of $20 million due to higher average balances and rates on short-term debt. The total interest expense decrease was also attributable to $8 million of lower interest on alternative financing debt and $18 million of lower interest on debt discount and reacquisition.
Other Income (Expense), Net. During 2019, Other income (expense), net increased $12 million primarily driven by $21 million of other income related to a 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 Nuclear Regulatory Commission ("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 $5 million decrease in miscellaneous income, resulting from prior year gains on the disposition of property and $2 million of unrealized losses on the Supplemental Executive Retirement Plan ("SERP") and Deferred Compensation Plan ("DCP") investments.
Other Net Periodic Benefit Cost
2019 Compared to 2018
Other net periodic benefit cost increased $2 million for the year ended September 30, 2019 as compared to the prior year. Other net periodic benefit cost is subject to significant economic assumptions, such as changes in the discount rate used to measure the benefit plans, that can materially impact TVA. However, TVA uses regulatory accounting to recognize other net periodic benefit cost as a regulatory asset 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. See Note 21 — Benefit Plans. In 2019, contributions exceeded U.S. GAAP pension expense resulting in additional amounts charged to other net periodic benefit cost.
2018 Compared to 2017
Other net periodic benefit cost decreased $502 million in 2018 as compared to the prior year. This decrease is primarily due to a decrease in pension expense for 2018, which is attributable to a one-time additional discretionary $500 million contribution to TVA’s pension plan in 2017, which was recognized as pension expense. TVA uses regulatory accounting to recognize pension expense as a regulatory asset 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.
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Liquidity and Capital Resources
Sources of Liquidity
TVA depends on various sources of liquidity to meet cash needs and contingencies. TVA's primary sources of liquidity
are cash from operations and proceeds from the issuance of short-term debt in the form of discount notes, along with periodic
issuances of long-term debt. TVA's balance of short-term debt typically changes frequently as TVA issues discount notes to
meet short-term cash needs and pay scheduled maturities of discount notes and long-term debt. The periodic amounts of short-term debt issued are determined by near-term expectations for cash receipts, cash expenditures, and funding needs, while
seeking to maintain a target range of cash and cash equivalents on hand.
In addition to cash from operations and proceeds from the issuance of short-term and long-term debt, TVA's sources of liquidity include a $150 million credit facility with the United States Department of the Treasury ("U.S. Treasury"), four long-term revolving credit facilities totaling $2.7 billion, and proceeds from other financings. See Note 13 — Debt and Other Obligations — Credit Facility Agreements. Other financing arrangements may include sales of receivables, loans, or other assets.
The TVA Act authorizes TVA to issue Bonds in an amount not to exceed $30 billion outstanding at any time. Power bonds outstanding, excluding unamortized discounts and premiums and net exchange losses from foreign currency transactions, at September 30, 2019 and 2018, were $21.4 billion (including current maturities) and $22.7 billion (including current maturities), respectively. The balance of Bonds outstanding directly affects TVA's capacity to meet operational liquidity needs and to strategically use Bonds to fund certain capital investments as management and the TVA Board may deem desirable. Other options for financing not subject to the limit on Bonds, including lease financings (see Lease Financings below and Note 10 — Variable Interest Entities), could provide supplementary funding if needed. Currently, TVA expects to have adequate capability to fund its ongoing operational liquidity needs and make planned capital investments over the next decade. See Lease Financings below, Note 10 — Variable Interest Entities, and Note 13 — Debt and Other Obligations for additional information.
TVA may from time to time seek to retire or purchase its outstanding debt through cash purchases and/or exchanges for securities, in open market purchases, privately negotiated transactions, or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, TVA's liquidity requirements, contractual restrictions, and other factors. The amounts involved may be material.
Debt Securities. TVA's Bonds are not obligations of the U.S., and the U.S. does not guarantee the payments of principal or interest on Bonds. TVA's Bonds consist of power bonds and discount notes. Power bonds have maturities of between one and 50 years. At September 30, 2019, the average maturity of long-term power bonds was 16.1 years, and the average interest rate was 4.65 percent. Discount notes have maturities of less than one year. Power bonds and discount notes have a first priority and equal claim of payment out of net power proceeds. Net power proceeds are defined as the remainder of TVA's gross power revenues after deducting the costs of operating, maintaining, and administering its power properties and payments to states and counties in lieu of taxes, but before deducting depreciation accruals or other charges representing the amortization of capital expenditures, plus the net proceeds from the sale or other disposition of any power facility or interest therein. In addition to power bonds and discount notes, TVA had long-term debt associated with certain VIEs outstanding at September 30, 2019. TVA also had secured notes outstanding at September 30, 2019, that were assumed in a prior year asset acquisition. See Lease Financing below, Note 10 — Variable Interest Entities, and Note 13 — Debt and Other Obligations for additional information.
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"). 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:

• | Operation, maintenance, and administration of its power system;

• | Tax equivalents;

• | Debt service on outstanding Bonds;

• | Payments to the U.S. Treasury in repayment of and as a return on the Power Program Appropriation Investment; and

• | Such additional margin as the TVA Board may consider desirable for investment in power system assets, retirement of outstanding Bonds in advance of maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected wit h TVA's pow er business, having 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. See Note 18 — Proprietary Capital — Appropriation Investment.

TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment in 2014; therefore, the repayment of this amount is no longer a component of rate setting.
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The rate test for the one-year period ended September 30, 2019, was calculated after the end of 2019, and TVA met the test's requirements.
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 the depreciation accruals and other charges representing the amortization of capital expenditures and 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.
The bondholder protection test for the five-year period ended September 30, 2015, was calculated after the end of 2015, and TVA met the test's requirements. TVA must next meet the bondholder protection test for the five-year period ending September 30, 2020, and expects to meet the test.
TVA uses proceeds from the issuance of discount notes, in addition to other sources of liquidity, to fund short-term cash needs and scheduled maturities of long-term debt.
The following table provides additional information regarding TVA's short-term borrowings.

Short-Term Borrowing Table
| At September 30, 2019 |  | For the year ended September 30, 2019 |  | At September 30, 2018 |  | For the year ended September 30, 2018 |  | At September 30, 2017 |  | For the year ended September 30, 2017
Gross Amount Outstanding (at End of Period) or Average Gross Amount Outstanding (During Period) |  |  |  |  |  |  |  |  |  |  |
Discount notes | $ | 922 |  |  | $ | 1,610 |  |  | $ | 1,217 |  |  | $ | 1,910 |  |  | $ | 1,999 |  |  | $ | 1,280 |
Weighted Average Interest Rate |  |  |  |  |  |  |  |  |  |  |
Discount notes | 2.152 | % |  | 2.320 | % |  | 2.045 | % |  | 1.500 | % |  | 1.000 | % |  | 0.668 | %
Maximum Month-End Gross Amount Outstanding (During Period) |  |  |  |  |  |  |  |  |  |  |
Discount notes | N/A |  |  | $ | 2,390 |  |  | N/A |  |  | $ | 2,722 |  |  | N/A |  |  | $ | 2,062 |

TVA ended the year at September 30, 2019, with a lower balance of short-term debt than at September 30, 2018, due primarily to higher operating cash flows. The average balance of short-term debt was lower in 2019 than 2018 due primarily to the timing of cash flows.
TVA generally uses proceeds from the issuance of power bonds to refinance maturing power bonds or other financing obligations, as necessary, or for other power system purposes. The total balance of power bonds may decline in periods where redemptions of power bonds exceed issuance due to net positive cash flow from operating and investing activities. TVA is on track to achieve its strategic debt goal of $21.8 billion by fiscal year 2023.
TVA issued $1.0 billion of power bonds during 2018 and no power bonds were issued in 2019. TVA redeemed $1.1 billion and $1.8 billion of power bonds during 2019 and 2018, respectively. For additional information about TVA debt issuance activity and debt instruments issued and outstanding at September 30, 2019 and 2018, including rates, maturities, outstanding principal amounts, and redemption features, see Note 13 — Debt and Other Obligations — Debt Securities Activity and Debt Outstanding.
TVA Bonds are traded in the public bond markets and are listed on the New York Stock Exchange ("NYSE") except for TVA's discount notes, the 2009 Series B power bonds, and the power bonds issued under TVA's electronotes® program. TVA's Putable Automatic Rate Reset Securities are traded on the NYSE under the exchange symbols "TVC" and "TVE." Other bonds listed on the NYSE are assigned various symbols by the exchange, which are noted on the NYSE's website. TVA has also listed certain bonds on foreign exchanges from time to time, including the Luxembourg, Hong Kong, and Singapore Stock Exchanges. See Item 1A, Risk Factors for additional information regarding the market for TVA's Bonds.
Although TVA Bonds are not obligations of the U.S., TVA, as a corporate agency and instrumentality of the U.S. government, may be impacted if the sovereign credit ratings of the U.S. are downgraded. Additionally, TVA may be impacted by how the U.S. government addresses situations of approaching its statutory debt limit. According to statements made by nationally recognized credit rating agencies, downward pressure on the ratings of the U.S. could eventually develop if there are no changes in current policies and budget deficits and the trajectory of debt begins to increase; additionally, current ratings factor in the prospect that debates over raising the debt ceiling of the U.S. government could continue to be protracted and difficult. The outlook on the ratings of the U.S. government and TVA is currently stable with all three agencies that provide ratings on TVA Bonds. TVA's rated senior unsecured Bonds are currently rated Aaa, AAA, and AA+. TVA's short-term discount notes are not rated.
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Lease Financings. TVA has entered into certain leasing transactions with special purpose entities ("SPEs") to obtain third-party financing for its facilities. These SPEs are sometimes identified as VIEs of which TVA is determined to be the primary beneficiary. TVA is required to account for these VIEs on a consolidated basis. See Note 10 — Variable Interest Entities and Note 13 — Debt and Other Obligations for information about TVA's lease financing activities. During 2017 and 2016, TVA acquired 100 percent of the equity interests in certain SPEs created for the purpose of facilitating lease financing. TVA may seek to enter into similar arrangements in the future. In March 2019, TVA made final rent payments under lease/leaseback transactions involving eight CTs, and in July 2019, these transactions were
terminated.
Summary Cash Flows
A major source of TVA's liquidity is operating cash flows resulting from the generation and sale of electricity. Cash, cash equivalents, and restricted cash were $322 million at both September 30, 2019 and 2018, and $311 million at September 30, 2017. A summary of cash flow components for years ended September 30 follows:
Cash provided by (used in):
Operating Activities. TVA's cash flows from operations are primarily driven by sales of electricity, fuel expense, and operating and maintenance expense. The timing and level of cash flows from operations can be affected by the weather, changes in working capital, commodity price fluctuations, outages, and other project expenses.
2019 Compared to 2018
Net cash flows provided by operating activities decreased $218 million for 2019 compared to 2018, primarily driven by timing of payments and increased cash used for fuel inventory and outage costs. These changes were partially offset by the timing of revenue collections, increased base revenue driven by the base rate adjustment that became effective October 1, 2018, and lower interest paid.
2018 Compared to 2017
Net cash flows provided by operating activities increased $1.2 billion for 2018 compared to 2017, as a result of
increases in base revenues, lower operating and maintenance expenses, and lower interest paid. Increases in base revenue
were attributable to increases in electricity sales primarily due to overall warmer than normal weather for much of 2018 and
record-setting low temperatures during the month of January 2018 and the base rate adjustment that became effective October
1, 2017. Lower operating expenses were driven by a one-time discretionary pension contribution in 2017 and decreases in
nuclear planned outage days. Additionally, interest paid decreased in 2018 due to lower average balances and rates on long-term debt.
Investing Activities. The majority of TVA's investing cash flows are due to investments to acquire, upgrade, or maintain generating and transmission assets, including environmental projects and the purchase of nuclear fuel.
2019 Compared to 2018
Net cash flows used in investing activities decreased $26 million for 2019 compared to 2018, driven by the completion of the Browns Ferry EPU in 2019 and the completion of the Allen CC, clean air controls project at Shawnee Fossil Plant ("Shawnee"), and manufacturing of the Watts Bar steam generator in 2018. These decreases were offset by an increase in expenditures for the Boone Dam and Pickwick South Embankment Remediation projects.
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2018 Compared to 2017
Net cash flows used in investing activities decreased by $267 million for 2018 compared to 2017, driven by the completion of Paradise CC, Allen CC, and the clean air controls at Gallatin Fossil Plant ("Gallatin") and Shawnee. With the completion of these projects, TVA does not foresee needing additional large, base-load generation units for at least the next decade. These decreases were partially offset by increases in nuclear fuel expenditures. Nuclear fuel expenditures vary depending on the number of outages and the prices and timing of purchases of uranium and enrichment services.
Financing Activities. TVA's cash flows provided by or used in financing activities are primarily driven by the timing and level of cash flows provided by operating activities, cash flows used in investing activities, and net issuance and redemption of debt instruments to maintain a strategic balance of cash on hand.
2019 Compared to 2018
Net cash flows used in financing activities decreased $181 million for 2019 compared to 2018. TVA had $1.4 billion in net debt redemptions in 2019 compared to $1.6 billion in net debt redemptions in 2018. TVA's financing activities continue to reflect an overall reduction in debt driven by strong financial performance and execution of long-range financial plans to reduce debt and keep TVA's electric rates competitive.
2018 Compared to 2017
Net cash flows used in financing activities increased $1.5 billion for 2018 compared to 2017. TVA had $1.6 billion in net
debt redemptions in 2018 compared to $29 million in net debt redemptions in 2017. The increase in redemptions is primarily due
to the $1.2 billion increase in operating cash flows, which resulted in additional debt reduction. These increases in redemptions
were partially offset by decreases in payments on lease and leasebacks due to the 2017 acquisition of the residual interests in a
lease/leaseback arrangement. See Note 11 — Other Long-Term Liabilities.
Cash Requirements and Contractual Obligations
The future planned capital expenditures for property, plant, and equipment additions, including clean air projects and new generation, and nuclear fuel are estimated to be as follows:

Estimated Capital Expenditures(1) For the year ended September 30
| 2020 |  | 2021 |  | 2022
Capacity expansion expenditures | $ | 353 |  |  | $ | 750 |  |  | $ | 1,064 |
Environmental expenditures | 254 |  |  | 207 |  |  | 143 |
Nuclear fuel | 366 |  |  | 374 |  |  | 325 |
Transmission expenditures | 503 |  |  | 527 |  |  | 432 |
Other capital expenditures(2) | 886 |  |  | 875 |  |  | 939 |
Total capital expenditures | $ | 2,362 |  |  | $ | 2,733 |  |  | $ | 2,903 |

Notes
(1) TVA plans to fund these expenditures with cash from operations and proceeds from power program financings. This table shows only expenditures that are currently planned. Additional expenditures may be required, among other things, for TVA to meet growth in demand for power in its service area or to comply with new environmental laws, regulations, or orders.
(2) Other capital expenditures are primarily associated with short lead time construction projects aimed at the continued safe and reliable operation of generating assets.
TVA continually reviews its capital expenditures and financing programs. The amounts shown in the table above are forward-looking amounts based on a number of assumptions and are subject to various uncertainties. Amounts may differ materially based upon a number of factors, including, but not limited to, changes in assumptions about system load growth, environmental regulation, rates of inflation, total cost of major projects, and availability and cost of external sources of capital. See Forward-Looking Information and Item 1A, Risk Factors.
TVA has certain obligations and commitments to make future payments under contracts, including contracts executed in connection with certain of the planned construction expenditures. The following table sets forth TVA's estimates of future payments at September 30, 2019. See Note 10 — Variable Interest Entities, Note 11 — Other Long-Term Liabilities, Note 13 — Debt and Other Obligations, Note 21 — Benefit Plans, and Note 22 — Commitments and Contingencies for a further description of these obligations and commitments.
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Commitments and Contingencies Payments due in the year ending September 30
| 2020 |  | 2021 |  | 2022 |  | 2023 |  | 2024 |  | Thereafter |  | Total
Debt(1) | $ | 1,952 |  |  | $ | 1,860 |  |  | $ | 1,028 |  |  | $ | 29 |  |  | $ | 1,022 |  |  | $ | 15,476 |  |  | $ | 21,367 |
Interest payments relating to debt(2) | 1,058 |  |  | 1,017 |  |  | 966 |  |  | 945 |  |  | 944 |  |  | 14,254 |  |  | 19,184 |
Debt of VIEs(3) | 40 |  |  | 41 |  |  | 43 |  |  | 40 |  |  | 36 |  |  | 937 |  |  | 1,137 |
Interest payments relating to debt of VIEs | 52 |  |  | 50 |  |  | 49 |  |  | 47 |  |  | 45 |  |  | 451 |  |  | 694 |
Notes payable | 23 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 23 |
Lease obligations |  |  |  |  |  |  |  |  |  |  |  |  |  |
Capital(4) | 53 |  |  | 53 |  |  | 53 |  |  | 55 |  |  | 51 |  |  | 418 |  |  | 683 |
Non-cancelable operating(5) | 33 |  |  | 31 |  |  | 15 |  |  | 5 |  |  | 3 |  |  | 2 |  |  | 89 |
Purchase obligations |  |  |  |  |  |  |  |  |  |  |  |  |  |
Power(6) | 317 |  |  | 316 |  |  | 295 |  |  | 187 |  |  | 170 |  |  | 1,041 |  |  | 2,326 |
Fuel(7) | 1,281 |  |  | 978 |  |  | 497 |  |  | 381 |  |  | 378 |  |  | 1,317 |  |  | 4,832 |
Other(8) | 55 |  |  | 48 |  |  | 60 |  |  | 39 |  |  | 22 |  |  | 230 |  |  | 454 |
Environmental Agreements | 1 |  |  | 2 |  |  | 2 |  |  | 2 |  |  | 1 |  |  | 4 |  |  | 12 |
Membership interests of VIEs subject to mandatory redemption | 3 |  |  | 3 |  |  | 3 |  |  | 2 |  |  | 1 |  |  | 16 |  |  | 28 |
Interest payments related to membership interests of VIEs subject to mandatory redemption | 2 |  |  | 2 |  |  | 2 |  |  | 1 |  |  | 1 |  |  | 7 |  |  | 15 |
Flood response commitment to NRC | — |  |  | 27 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 27 |
Unfunded loan commitments | 7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 7 |
Long-term monitoring costs - Kingston ash spill | 1 |  |  | 1 |  |  | 1 |  |  | — |  |  | 1 |  |  | 7 |  |  | 11 |
Payments on other financings(9) | 60 |  |  | 217 |  |  | 36 |  |  | 10 |  |  | 10 |  |  | 223 |  |  | 556 |
Retirement Plan(10) | 300 |  |  | 300 |  |  | 300 |  |  | 300 |  |  | 300 |  |  | 3,600 |  |  | 5,100 |
Total | $ | 5,238 |  |  | $ | 4,946 |  |  | $ | 3,350 |  |  | $ | 2,043 |  |  | $ | 2,985 |  |  | $ | 37,983 |  |  | $ | 56,545 |

Notes
(1) 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.
(2) Includes the effects of interest rate derivatives employed to manage interest rate risk.
(3) Debt of VIEs does not include the non-cash item of unamortized debt issue costs of $9 million.
(4) Includes the interest component of capital leases based on the interest rates stated in the lease agreements and excludes certain related executory costs. Minimum commitments related to executory costs are included in purchase obligations.
(5) Does not include purchased power agreements of $139 million that are accounted for as operating leases and included in power purchase obligations.
(6) Includes commitments for energy and/or capacity under power purchase agreements from coal-fired, hydroelectric, diesel, and gas-fired facilities, as well as transmission service agreements to support purchases of power from the market.
(7) Includes commitments to purchase nuclear fuel, coal, and natural gas, as well as related transportation and storage services.
(8) Primarily includes long-term service contracts, contracts that contain minimum purchase levels for the purchase of limestone along with related storage and transportation, and contractual obligations related to load control programs.
(9) Includes leasebacks of $50 million, $207 million, and $25 million for 2020, 2021, and 2022, respectively.
(10) Pursuant to amendments to the TVA Retirement System ("TVARS") Rules and Regulations that became effective October 1, 2016, TVA will contribute to TVARS for a period of 20 years (2017-2036) or, if earlier, through the fiscal year in which it is determined by actuarial valuation that TVARS has reached and remained at a 100 percent funded status, which is an amount not less than the greater of (a) the minimum required TVARS actuarial valuation contribution or (b) $300 million.
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.
EnergyRight® Solutions Program. TVA purchases certain loans receivable from its LPCs in association with the EnergyRight® Solutions program. Depending on the nature of the energy-efficiency project, loans may have a maximum term of five years or 10 years. The loans receivable are then transferred to a third-party bank with which TVA has agreed to repay in full any loan receivable that has been in default for 180 days or more or that TVA has determined is uncollectible. As of September 30, 2019, the total carrying amount of the loans receivable, net of discount, was approximately $101 million. Such amounts are not reflected in the Commitments and Contingencies table above. The total carrying amount of the financing obligation was approximately $113 million at September 30, 2019. See Note 7 — Other Long-Term Assets and Note 11 — Other Long-Term Liabilities for additional information.
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Off-Balance Sheet Arrangements
At September 30, 2019, TVA had no off-balance sheet arrangements.
Key Initiatives and Challenges
Distributed Energy Resources
Consumer desire for energy choice, among other things, is driving the expectation for flexible options in the electric industry. TVA and LPCs are working together to leverage the strengths of the Tennessee Valley public power model to provide distributed energy solutions that are economical, sustainable, and flexible. TVA will focus on the safety and reliability impacts of these resources as they are interconnected to the grid and will ensure that the pricing of electricity remains as low as feasible. Additional regulatory considerations and analysis may be required as the distributed energy resources ("DER") market, technologies, and programs evolve. TVA is working to develop pricing and regulatory structures with a deliberate and thoughtful analysis of each current and future program offering. This requires strong partnerships with LPCs to give customers choices and provide end-use consumers the flexibility they desire.
In May 2017, the TVA Board authorized up to $300 million to be spent over the next 10 years, subject to annual budget availability and necessary environmental reviews, to build an enhanced fiber optic network by adding up to 3,500 additional miles that will better connect its operational assets. Fiber is a vital part of TVA's modern communication infrastructure. The new fiber optic lines will improve the reliability and resiliency of the generation and transmission system while enabling the system to better accommodate DER as they enter the market. As of September 30, 2019, TVA had installed 483 miles of lines. As of September 30, 2019, TVA had spent $79 million on installation of the fiber optic lines and expects to spend an additional $221 million to complete the project.
Changing Customer Preferences
As more consumers and businesses are demanding cleaner and greener energy, the utility industry is evolving to meet those needs. As TVA also evolves, it will see impacts to the way it does business through the pricing of products, transmission of energy, and development of new products and services for its customers in support of changing customer preferences and its economic development efforts. End-use customers are becoming more technologically sophisticated and want greater control over their energy usage. Many companies are focusing more on sustainability and requiring more energy efficiency as well as cleaner, greener, more renewable energy options. The continuing challenge for TVA and others is finding ways to meet the needs and preferences of customers while successfully developing flexible pricing models to accommodate the evolving markets.
Low-Income Energy Efficiency Program. Through the Home Uplift Program, TVA is partnering with LPCs, state and local governments, non-profit agencies, energy efficiency advocates, and the Tennessee Valley Public Power Association to complete home evaluations and make high-impact home energy upgrades for qualifying homeowners. In addition, TVA and LPCs conduct workshops to educate homeowners about low and no-cost energy efficiency upgrades that improve their quality of life.
Renewable Power Purchase Agreements. In order to meet customer preferences and requirements for cleaner and greener energy, TVA has entered into certain power purchase agreements ("PPAs") with renewable resource providers during 2019. These agreements are the latest to stem from TVA's 2017 request for proposals for renewable energy. During the first quarter of 2019, TVA signed four solar PPAs for 674 MW of solar generation at sites in Tennessee and Alabama. These four solar projects are expected to come online in 2021. TVA will procure the renewable energy and sell the resulting Renewable Energy Certificates to specific customers, allowing TVA to increase its renewable energy portfolio without additional costs to other Valley customers. These agreements are part of progressive partnerships that align the core values of TVA and the public power model with the desire of TVA's customers for renewable energy.
Renewable Power Solutions. During its February 2019 meeting, the TVA Board approved new renewable power solutions, including a utility-scale option and a mid-scale option, that better equip TVA and LPCs with the flexibility to meet changing end-use customer needs. The utility-scale option, referenced at the February 2019 TVA Board meeting as the Flexibility Renewable Option, is implemented by a Renewable Investment Agreement, which aggregates demand through a competitive procurement process. The mid-scale option, also known as the Flexibility Research Project, is a joint project with LPCs to enable solutions for situations where the end-use consumer needs onsite renewable or distributed generation and for TVA to gain market knowledge and operational insights from these research projects.
In addition, TVA issued a request for proposal in April 2019 for up to 200 MW of new renewable energy. The ultimate volume contracted will align to TVA customers' demand for renewable energy, allowing TVA to increase its renewable energy portfolio without additional costs to other Valley customers. TVA accepted proposals through mid-May 2019 and anticipates making selections during the first quarter of 2020.
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Integrated Resource Planning
During 2018 and 2019, TVA conducted a study of its energy resources in order to update and replace the IRP that was accepted by the TVA Board in 2015. The IRP is a comprehensive study that provides direction on how to best meet future power demand by identifying the need for generating capacity, determining the best mix of resources, and evaluating the evolving role of DER. The IRP considers many views of the future to determine how TVA can continue to provide low-cost, reliable electricity, support environmental stewardship, and spur economic development in the Tennessee Valley over the next 20 years. To inform TVA's next long-term financial plan and proactively address the changing utility marketplace, TVA began this work sooner than originally planned.
To ensure TVA best meets projected future needs, TVA will continue its tradition of innovation in each IRP. The 2011 IRP focused on diversifying and modernizing its generation portfolio, part of which included adding cost-effective renewables. The 2015 IRP identified DER as a growing trend in the utility industry and designed a mechanism where energy efficiency could be chosen as a resource. The 2019 IRP explored various DER scenarios, considering the speed and amount of DER penetration, and improved TVA's understanding of the impact and benefit of system flexibility with increasing renewable and distributed resources.
During the IRP process, TVA - with significant input from stakeholders and the public - considered a wide range of future scenarios, various business strategies, and a diverse mix of power-generation resources to build on TVA's existing asset portfolio. IRP study results show:

• | There is a need for new capacity in all scenarios to replace expiring or retiring capacity.

• | Solar expansion plays a substantial role in all future scenarios.

• | Gas, energy storage, and demand response additions provide reliability and/or flexibility to TVA's system.

• | No baseload resources (designed to operate continuously) are added, highlighting the need for operational flexibility in the resource portfolio.

• | Additional coal retirements occur in certain futures.

• | Energy efficiency levels depend on market depth and cost-competitiveness.

• | Wind could play a role if it becomes cost-competitive.

• | In all cases, TVA will continue to provide for economic growth in the Tennessee Valley.

The IRP was developed with input from the public and contributions from a working group of stakeholders from LPCs, environmental organizations, and other public and private entities with a vested interest, including an extensive public outreach that included a series of open meetings around the Tennessee Valley. The final 2019 IRP was approved by the TVA Board at its August 2019 meeting.
Natural Resource Plan
TVA is updating its Natural Resource Plan ("NRP"), which was completed in 2011 to guide TVA's management of the public lands and waters within its seven-state service area. TVA remains committed to a balanced management approach and is considering changes to the NRP that include objectives and programs for each focus area and a flexible approach for long-term planning. These changes align with TVA's mission and will help TVA be better equipped to prioritize funding plans and create efficiencies in business planning and stewardship project implementation. During 2019, TVA hosted public meetings around the Valley and released the draft NRP and the associated Supplemental Environmental Impact Statement ("SEIS") for public review and comment. TVA is currently drafting the final SEIS and 2020 NRP, which are expected to be published in the second quarter of 2020.
Generation Resources
Extreme Flooding Preparedness. Updates to the TVA analytical hydrology model completed in 2009 indicated that under "probable maximum flood" conditions, some of TVA's dams might not have been capable of regulating the higher flood waters. A "probable maximum flood" is an extremely unlikely event; however, TVA is obligated to provide protection for its nuclear plants against such events. As a result, TVA installed a series of modifications at four dams.
Since 2009, TVA has performed further hydrology modeling of portions of the TVA watershed using updated modeling tools. The revised hydrology models were reviewed and approved by the NRC for Watts Bar Units 1 and 2. However, TVA identified an error in the modeling that will require the models for Watts Bar Units 1 and 2 to be resubmitted. TVA plans to resubmit models for Watts Bar Units 1 and 2 during the first quarter of 2020. In addition, TVA plans to submit models for Sequoyah Nuclear Plant ("Sequoyah") Units 1 and 2 during the first quarter of 2020. TVA will subsequently address conditions at Browns Ferry as needed. TVA is deferring the decision on the need for additional modifications until after the modeling work is complete.
As of September 30, 2019, TVA had spent $153 million on the modifications and improvements related to extreme flooding preparedness and expects to spend up to an additional $27 million to complete the modifications.
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NRC Seismic Assessments. On May 9, 2014, the NRC notified licensees of nuclear power reactors in the central and eastern U.S. of the results of seismic hazard screening and prioritization evaluations performed by unit owners and reviewed by the NRC staff. Because the seismic hazards for Browns Ferry, Sequoyah, and Watts Bar had increases in seismic parameters beyond the technical information available when the plants were designed and licensed, TVA must conduct seismic risk evaluations for these plants. TVA completed the risk evaluation for Watts Bar and submitted it to the NRC on June 30, 2017; the evaluation concluded that no additional actions were required. The NRC completed its review of the Watts Bar evaluation in July 2018 and concluded that no further response or regulatory actions were required. The evaluations for Browns Ferry and Sequoyah are due by December 31, 2019.
Mitigation of Beyond-Design-Basis Events. NRC rulemaking has been developed to codify the requirements promulgated by orders related to beyond-design-basis flooding and seismic events discussed above. The NRC Commissioners approved the final rule in September 2019. TVA plans to implement requirements for Sequoyah and Watts Bar by 2022 and for Browns Ferry by 2023. A gap review of the revised rule has been performed and no new gaps to compliance were identified. Actions to complete flood and seismic assessments are still ongoing. See Extreme Flooding Preparedness and NRC Seismic Assessments above.
Baffle-Former Bolt Degradation. In July 2016, Westinghouse Electric Co., LLC ("Westinghouse") issued a Nuclear Safety Advisory Letter ("NSAL") 16-01 that addressed recently identified degradation of baffle-former bolts in some U.S. pressurized water reactors ("PWRs"). Baffle-former bolts help hold together a structure inside certain reactor vessels. Sequoyah Units 1 and 2, both PWRs, are referenced in the NSAL. Visual inspections of baffle-former bolts in Sequoyah Units 1 and 2 during 2017 refueling outages showed no degradation of baffle-former bolts. TVA completed ultrasonic testing for Unit 1 in the third quarter of 2018 and Unit 2 in the first quarter of 2019. Results for both units were within acceptable standards. Retesting will not be required until 2028.
Work Environment at Nuclear Plants. In March 2016, the NRC issued a Chilling Effect Letter ("CEL") to TVA regarding work environment concerns identified at Watts Bar. In June 2018, the NRC conducted a follow-up inspection at Watts Bar and noted some improvement. In the mid-cycle assessment letter issued in June 2018, the NRC issued a Cross Cutting Issue ("CCI") in safety conscious work environment and outlined the closure criteria for both the CEL and the CCI. In August 2018, the NRC documented a chilled work environment in an additional department. TVA is working to implement actions to address the issues in the additional department and closure criteria for the CEL and CCI.
Tritium-Producing Burnable Absorber Rods. TVA was a cooperating agency in the February 2016 Department of Energy ("DOE") Final SEIS for the Production of Tritium in a Commercial Light Water Reactor. On April 5, 2017, due to an anticipated need for more tritium-producing burnable absorber rods ("TPBARs"), the DOE announced its preferred alternative for irradiation services, which included use of an additional reactor. As a result of TVA's assessment and concurrence with the DOE's alternative, TVA submitted a license amendment request to the NRC in December 2017 to authorize the irradiation of TPBARs in Watts Bar Unit 2. The NRC approved the request on May 22, 2019. TVA is projecting to begin tritium production in Watts Bar Unit 2 in the fall of 2021. The DOE's decision also allows for irradiation of TPBARs at Sequoyah in the future; however, TVA does not have plans to employ Sequoyah units for tritium production in the near term.
Extended Power Uprate. TVA has undertaken an EPU project at Browns Ferry to increase the amount of electrical generation capacity of its reactors. The license for each reactor was amended to allow reactor operation at the higher power level. The Browns Ferry EPU license amendments were approved by the NRC on August 14, 2017, following a nearly two-year review.
The project involved extensive engineering analyses and modification and replacement of certain existing plant components to enable the units to produce the additional power requested by the license amendments. The project is estimated to cost approximately $475 million. As of September 30, 2019, physical work on all units was complete and the generating capacity is expected to increase by an estimated 465 MW after sufficient run time to validate the new capacity.
Plant Closures. During its August 2018 meeting, the TVA Board approved a plan to perform assessments of Bull Run and Paradise. These assessments included resiliency studies for fuel and transmission, financial considerations, and Environmental Assessments 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 Paradise would not be restarted after January 2020 due to the plant's material condition. See Note 6 — Plant Closures.
Coal Combustion Residual Facilities. TVA has committed to a programmatic approach for the elimination of wet storage of CCRs within the TVA service area. Under this program (the "CCR Conversion Program"), TVA is converting all operational coal-fired plants to dry CCR storage and closing all wet storage facilities.
Dry generation and dewatering projects. Conversion of coal plant CCR wet processes to dry generation or dewatering is complete at Bull Run, Shawnee, and Kingston Fossil Plant ("Kingston"). Construction is underway at Gallatin and is scheduled for completion by December 2019. Construction is also underway at Cumberland Fossil Plant ("Cumberland") and is
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scheduled for completion in late 2020. Fly ash and gypsum conversion projects at Paradise were complete during the third quarter of 2019.
Landfills. TVA has made strategic decisions to build and maintain lined and permitted dry storage facilities on TVA-owned property at several TVA locations, allowing these facilities to operate beyond existing dry storage capacity. Currently, lined and permitted dry storage facilities are completed and operational at Bull Run, Kingston, and Gallatin, and a lined dry storage facility at Paradise has been constructed but is not yet operational. A lined dry storage facility at Shawnee is currently under construction with completion scheduled for September 2020. Construction of a lined dry storage facility at Cumberland is expected to start in 2021. Kingston's permitted lined dry storage expansion is scheduled for completion in 2021. TVA is designing and permitting a lateral expansion of the existing landfill at Gallatin. Additionally, TVA is initiating the design and permitting process for a new lined landfill at Bull Run, but no decision to construct the facility has been made at this time. Construction of additional lined facilities may occur to support future business requirements.
Wet CCR impoundment closures. TVA is working to close wet CCR impoundments in accordance with federal and state requirements. Closure project schedules and costs are driven by the selected closure methodology (such as closure-in-place or closure-by-removal). Closure initiation dates are driven by environmental regulations. TVA's predominant closure methodology is closure-in-place, with exceptions at certain facilities. TVA issued an environmental impact statement ("EIS") in June 2016 that addresses the closure of CCR impoundments at TVA's coal-fired plants. TVA issued its associated Record of Decision in July 2016. Although the EIS was designed to be programmatic in order to address the mode of impoundment closures, it specifically addressed closure methods at 10 impoundments. TVA subsequently decided to close those impoundments. The method of final closure for each of these facilities will depend on various factors, including the results of studies conducted pursuant to NEPA and approval by appropriate state regulators. Additional NEPA studies will be conducted as other facilities are designated for closure. See Note 12 — Asset Retirement Obligations.
Groundwater monitoring. Compliance with the EPA's CCR rule (the "CCR Rule") as well as other requirements will require additional engineering and analysis as well as implementation of a comprehensive groundwater monitoring program. As further analyses are performed, including evaluation of monitoring results, there is the potential for additional costs for investigation and/or remediation. TVA expects to continue to evaluate and update these cost estimates.
In compliance with the CCR Rule, TVA published the results of additional groundwater testing at TVA's CCR facilities on March 1, 2019. The results included values above groundwater protection standards for some constituents at several CCR units. Accordingly, TVA will have to cease sending CCR and non-CCR waste streams to any impacted unlined CCR surface impoundments no later than October 31, 2020 (and potentially earlier due to location demonstration results) and initiate additional corrective actions for groundwater. TVA is developing these corrective actions and published Assessment of Corrective Measures reports to its CCR website in August 2019. Due to location demonstration results, TVA has already ceased sending waste streams to one impoundment at Allen and three impoundments at Gallatin. As required by the CCR Rule, TVA will continue to publish reports in the second quarter of each year on annual groundwater monitoring and corrective actions at its active CCR facilities.
TVA has been involved in two lawsuits concerning the CCR facilities at Gallatin. One of these cases was resolved by the entry of a consent order that became effective July 31, 2019. TVA agreed to close the existing wet ash impoundments by removal, either to an onsite landfill or to an offsite facility. TVA may also submit a plan that allows for beneficial reuse. TVA is currently conducting additional studies and environmental reviews to support its determination of the specific removal plans. See Note 12 — Asset Retirement Obligations and 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.
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.
As of September 30, 2019, TVA had spent approximately $1.8 billion on its CCR Conversion Program. TVA expects to spend an additional $1.2 billion on the CCR Conversion Program through 2024. These estimates may change depending on the final closure method selected for each facility. Once the CCR Conversion Program is completed, TVA will continue to undertake certain CCR projects, including building new landfill cells under existing permits and closing existing cells once they reach capacity.
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 by employees of a
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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 this or similar cases could have broader implications for the utility industry. See Note 22 — Commitments and Contingencies — Legal Proceedings.
River Management. The Tennessee Valley experienced above normal rainfall and runoff for the first three quarters of 2019 and below normal rainfall and runoff during the fourth quarter of 2019. Despite the below normal rainfall and runoff in the fourth quarter of 2019, adequate reservoir storage accumulated during the preceding three quarters of 2019 helped TVA meet its river system commitments, including managing minimum river flows for navigation, generating low-cost hydroelectric power, maintaining water quality and water supply, and providing recreational opportunities for the Tennessee Valley. In addition, having cool water available helps TVA to meet thermal compliance and support normal operation of TVA's nuclear and fossil-fueled plants, while oxygenating water helps fish species remain healthy. Rainfall and runoff in the Tennessee Valley in 2019 were 131 percent and 154 percent of normal, respectively.
Significant flooding occurred in portions of the Tennessee Valley in February 2019. During this time, the Tennessee Valley received 11.6 inches of rainfall, which was 269 percent of normal. Although many locations along the Tennessee River reached or exceeded flood stage, TVA's efforts, including storing water in large tributary reservoirs, accounted for approximately $1.6 billion in avoided damages in areas such as Chattanooga, Tennessee.
Small Modular Reactors. TVA submitted an Early Site Permit Application ("ESPA") for review by the NRC in May 2016. NRC staff concluded their environmental review and issued a Final EIS in April 2019. NRC staff concluded their safety review and issued a Final Safety Evaluation Report in June 2019. The Commission held the statutorily required Mandatory Hearing on August 14, 2019, and a vote on permit issuance is expected by December 31, 2019. The ESPA is based on the potential construction and operation of two or more small modular reactors ("SMRs") units at TVA's Clinch River site in Oak Ridge, Roane County, Tennessee. As of September 30, 2019, TVA had spent $74 million on this project. Since June 2015, the DOE has funded 50 percent of TVA's work on the ESPA through an interagency agreement. Additional spend will be determined based on future project development.
TVA is developing the Clinch River site at a pace consistent with progress being made by developers on the engineering and licensing of SMR designs. The project has a great deal of flexibility at this early stage and by working to reduce licensing risk, TVA expects to be in a position to build an SMR if and when additional power sources are needed. Any decision to construct an SMR would require approval by the TVA Board.
Seismic Activity. The TVA service area experienced several earthquakes during the first nine months of 2019. Inspections were completed and no impacts to the TVA generating facilities or dams were identified. TVA's generating system continued to operate safely.
Dam Safety and Remediation Initiatives
Assurance Initiatives. TVA has an established dam safety program, which includes procedures based on the Federal Guidelines for Dam Safety, with the objective of reducing the risk of a dam safety event. The program is comprised of various engineering activities for all of TVA's dams including safety reassessments using modern industry criteria and the new probable maximum flood and site-specific seismic load cases. One aspect of the guidelines is that dam structures will be periodically assessed to assure that TVA's dams meet current design criteria. These assessments include material sampling of the dam and foundational structures and detailed engineering analysis. TVA will continue preventative and ongoing maintenance as a part of this safety program.
Boone Dam Remediation. In October 2014, a sinkhole was discovered near the base of the earthen embankment at Boone Dam, and a small amount of water and sediment was found seeping from the river bank below the dam. TVA identified underground pathways contributing to the seepage and prepared a plan to repair the dam, which consists of the construction of
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a composite seepage barrier wall in the dam's earthen embankment. TVA has completed grouting and construction of an upstream and downstream buttress. Installation of the concrete cut-off wall elements is in process.
As design and construction plans are finalized, the estimated cost and duration continue to be refined. As of September 30, 2019, TVA had spent $173 million related to this project and expects to spend an additional $283 million through 2023. TVA expects the reservoir to return to normal operations in 2022 and is continuing to work with the community to help mitigate local impacts of the extended drawdown.
Pickwick South Embankment Remediation. Reassessments of Pickwick Landing Dam ("Pickwick") found low safety factors for post-earthquake stability indicating that the dam is at significant risk for slope stability failure following a seismic event in portions of the south embankment. Slope stability failure could lead to a breach of the south embankment and loss of the reservoir, resulting in loss of life and damage to property downstream, disruption to navigation, and loss of generation and recreation.
TVA is planning to upgrade the south embankment by constructing berms on the upstream and downstream slopes. The design phase of the project began during the first quarter of 2017 and is now completed. Construction began in the spring of 2019, and the project is currently estimated to be completed in two years, but could take longer depending on successful construction sequencing. As of September 30, 2019, TVA had spent $71 million related to this project and expects to spend an additional $77 million.
Surplus Property
TVA continues to study its real estate portfolio for the purpose of aligning its real estate holdings with TVA's strategic direction. A comprehensive assessment of its real estate holdings has been completed, and TVA is implementing a strategy aimed at reducing cost and right-sizing its portfolio as part of the effort.
Bellefonte Nuclear Plant. On November 14, 2016, following a public auction, TVA entered into a contract to sell substantially all of the Bellefonte site to Nuclear Development, LLC, for $111 million. Nuclear Development, LLC, paid TVA $22 million on November 14, 2016, with the remaining $89 million due at closing. Nuclear Development, LLC, had up to two years from November 14, 2016, to close on the property, and TVA agreed to maintain the site until closing. Nuclear Development, LLC, requested and was granted an extension of the initial closing date to November 30, 2018. Nuclear Development, LLC, failed to obtain NRC approval of the transfer of the Bellefonte nuclear licenses. TVA determined that the Atomic Energy Act required that this approval be obtained before closing. TVA declined to provide a second extension of the purchase agreement. On November 30, 2018, Nuclear Development, LLC, filed suit against TVA in the United States District Court for the Northern District of Alabama. See Note 22 — Commitments and Contingencies — Legal Proceedings for a discussion of the lawsuit filed by Nuclear Development, LLC.
Knoxville Property. In 2016, TVA completed a comprehensive assessment of its real estate holdings in the Knoxville, Tennessee region including the Knoxville Office Complex ("KOC") and adjacent Summer Place Complex ("SPC"). As a result of this study and a subsequent environmental assessment in 2017, TVA is in the process of consolidating its Knoxville area employees into the West Tower of the KOC or a centralized field office in Norris, Tennessee. As part of this consolidation effort, TVA may convey the SPC and the majority of the East Tower of the KOC.
Regulatory Compliance
Steam-Electric Effluent Guidelines. In November 2015, the EPA published a final rule revising the existing
steam-electric effluent limitation guidelines ("ELGs"). The ELGs update the existing technology-based water discharge limitations for power plants. Compliance with new requirements is required in the 2018-2023 timeframe and will necessitate major upgrades to wastewater treatment systems at all coal-fired plants. Dry fly ash handling is mandated by the rule. The rule also requires either dry bottom ash handling systems or "no discharge" recycle of bottom ash transport waters, and new technology-based limits on flue gas desulfurization ("FGD") (scrubber) wastewater require primary physical/chemical treatment and secondary biological treatment to meet extremely low limits for arsenic, mercury, and selenium.
The EPA published a rule in September 2017, postponing certain compliance/applicability dates to provide the EPA time to review and revise, as necessary, the 2015 ELGs for FGD wastewater and bottom ash transport water. The EPA delayed the compliance dates for these two waste streams from the 2018-2023 timeframe to 2020-2023. However, the 2018-2023 applicability dates and the accompanying requirements for fly ash transport water, flue gas mercury control wastewater, and gasification wastewater remain unchanged. While the EPA reconsiders the limits for FGD wastewater and bottom ash transport water, states have issued National Pollutant Discharge Elimination System ("NPDES") permits for all of TVA's active coal facilities based on the 2015 ELGs, recognizing that the permits may need to be reopened to incorporate modifications to those ELGs.
TVA currently has four plants with wet scrubbers that may be subject to new scrubber-related limits, the largest being Cumberland. With the recent Board approval of accelerated retirement for Bull Run and Paradise, these plants may be exempted from the imposition of new scrubber-related limits, either as a result of the rule reconsideration currently underway or
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due to the retirement of the units prior to the regulatory deadline. TVA is working to address future compliance with the ELGs at Cumberland given its unique "once-through" scrubber design. Compliance with the current rule at Cumberland without modification to address the unique design could cause TVA to incur disproportionately high costs at Cumberland or experience other operational outcomes which TVA cannot predict at this time.
Allen Groundwater Investigation. The CCR Rule required TVA to implement a comprehensive groundwater monitoring program at units subject to the rule. As a result of this groundwater monitoring program, TVA reported to the Tennessee Department of Environment and Conservation ("TDEC") in May 2017 elevated levels of arsenic, lead, and fluoride in groundwater samples collected from two shallow-aquifer groundwater monitoring wells around the Allen East Ash Disposal Area. TVA, under the oversight of TDEC, conducted a remedial investigation into the nature and extent of the contamination. In March 2018, TVA submitted a draft Remedial Investigation Report to TDEC which was revised after discussions with TDEC and additional investigation. TVA submitted the Final Updated Remedial Investigation Report to TDEC on May 31, 2019.
The remedial investigation confirmed that the high arsenic, fluoride, and lead concentrations are limited to the shallow alluvial aquifer in the north and south areas of the Allen East Ash Disposal Area. These areas are not adversely impacting the Memphis aquifer, which is the source of the public drinking water supply. All samples taken from the Memphis aquifer through TVA production wells were below the EPA drinking water standards. As the result of a pumping test conducted on TVA production wells at the nearby Allen CC by the United States Geological Survey and the University of Memphis, TVA is committed to not operating these production wells until additional data supports safe use. TVA constructed water tanks on site and is purchasing cooling water from Memphis Light, Gas and Water. The use of water tanks rather than the wells may impose some operational restrictions on the Allen CC due to the lower availability of cooling water.
On March 14, 2019, TDEC approved TVA's interim groundwater monitoring plan. TVA will sample the monitoring wells around the Allen East Ash Disposal Area quarterly throughout CY 2019. TVA will prepare a memorandum following each sampling event, and an annual report will be issued. The groundwater monitoring plan will be reviewed and modified as required to support the project needs. TVA is currently in the process of finalizing and initiating the interim response action for a groundwater extraction system to control and begin treating the shallow groundwater that contains elevated concentrations of arsenic. TVA began dewatering the Allen East Impoundment in September 2019.
TVA is evaluating closure options for the Allen East Ash Disposal Area, as well as the nearby West Ash Impoundment, through an EIS pursuant to NEPA. In March 2019, TVA released its public scoping report, which eliminated closure-in-place as an alternative. On October 4, 2019, the draft EIS was published for a 45-day public comment period.
Ratemaking
TVA, LPCs, and directly served industries have worked collaboratively in recent years to develop changes to rates that focus on TVA's long-term pricing efforts and the changing needs of customers in the Tennessee Valley. These changes have improved pricing by better aligning rates with underlying cost drivers and by sending improved pricing signals, while maintaining competitive industrial rates and keeping residential rates affordable.
At its May 10, 2018 meeting, the TVA Board approved a rate change that reduced wholesale energy rates for Standard Service (residential and small commercial customers) and introduced a GAC at an offsetting rate to better recover fixed costs. Recognizing the need for flexibility, all LPCs were presented with the option to implement the wholesale changes in October 2018 or defer the implementation of the GAC until October 2019. Seventy-nine LPCs elected to implement the wholesale changes in October 2018, while the remaining 75 LPCs implemented the wholesale changes in October 2019.
At its May 9, 2019 meeting, the TVA Board approved a change to the wholesale power rate schedules to provide a mechanism to adjust the GAC for large changes in LPC load. This change helps ensure the equitable administration of the GAC.
At its August 22, 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 to the Valley, 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, which represents 56 percent of total operating revenues in 2019.
Safeguarding Assets
Physical Security — Non-Nuclear Asset Protection. TVA utilizes a variety of security technologies, security awareness activities, and security personnel to prevent sabotage, vandalism, and thefts. Any of these activities could negatively impact the ability of TVA to generate, transmit, and deliver power to its customers. TVA's Police and Emergency Management personnel are active participants with numerous professional and peer physical security organizations in both the electric industry and law enforcement communities.
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Physical attacks on transmission facilities across the country have heightened awareness of the need to physically protect facilities. TVA continues to work with the North American Electric Reliability Corporation ("NERC"), the SERC Reliability Corporation, the North American Transmission Forum, and other utilities to implement industry approved recommendations and standards.
Nuclear Security. Nuclear security is carried out in accordance with federal regulations as set forth by the NRC. These regulations are designed for the protection of TVA's nuclear power plants, the public, and employees from the threat of radiological sabotage and other nuclear-related terrorist threats. TVA has security forces to guard against such threats.
Cybersecurity. TVA operates in a highly regulated environment with respect to cybersecurity. TVA's cybersecurity program aligns or complies with the Federal Information Security Management Act, the NERC Critical Infrastructure Protection requirements, and the NRC requirements for cybersecurity, as well as industry best practices. As part of the U.S. government, TVA coordinates with and works closely with the Department of Homeland Security and the United States Computer Emergency Readiness Team ("US-CERT"). US-CERT functions as a liaison between the Department of Homeland Security and the public and private sectors to coordinate responses to security threats from the internet.
The risk of cybersecurity events such as malicious code attacks, unauthorized access attempts, and social engineering attempts continues to intensify. While TVA and its third-party vendors and service providers have been, and will likely continue to be, subjected to such attacks and attempts to disrupt operations, to date the attacks have not impacted TVA's ability to operate as planned. See Item 1A, Risk Factors — Operational Risks — TVA's facilities and information infrastructure may not operate as planned due to cyber threats to TVA's assets and operations.
Over the last few years, there has been an increase of malicious cyber activity across all industries, including the energy sector. This activity has caused the need for heightened awareness and preparedness. TVA is leveraging federal and other partners to better identify, detect, protect, and respond to these potential attacks. While there have been incidents of phishing and attempted fraud against TVA and its vendors and service providers, these events have not had a significant or material impact on business or operations.
Transmission Assets. In addition to physical and cybersecurity attacks, TVA's transmission assets are vulnerable to various types of electrically charged energy disruptions such as those from geomagnetic disturbances ("GMDs") and electromagnetic pulses ("EMP"). Because the effects of GMD and EMP are similar, they are often considered together. In September 2016, the Federal Energy Regulatory Commission ("FERC") approved a new standard to address GMD events, and in November 2018, FERC approved a revision to the standard. TVA has met the requirements of the original standard and most of the requirements of the revised standard, and has evaluated the effects of solar storms ranging from NERC's reference case to possible extreme levels. TVA continues as an active participant with NERC in this field. The most serious threats from EMP are those caused by high-altitude nuclear explosions. Like others in the industry, TVA is coordinating with federal and state authorities, NERC, Electric Power Research Institute ("EPRI"), and other grid owners and operators to address this concern.
Critical Accounting Policies and Estimates
TVA's consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"), which require management to make estimates, judgments, and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Each of these estimates varies in regard to the level of judgment involved and its potential impact on TVA's financial results. Estimates are deemed critical either when a different estimate could have reasonably been used, or where changes in the estimate are reasonably likely to occur from period to period, and such use or change also would materially impact TVA's financial condition, results of operations, or cash flows. TVA's critical accounting policies are also discussed in Note 1 of the Notes to Consolidated Financial Statements.
TVA believes that its most critical accounting policies and estimates relate to the following:

• | Regulatory Accounting;

• | AROs; and

• | Pension and Other Post-Retirement Benefits.

Management has discussed the development, selection, and disclosure of critical accounting policies and estimates with the Audit, Risk, and Regulation Committee of the TVA Board. While TVA's estimates and assumptions are based on its knowledge of current events and actions it may undertake in the future, actual results may ultimately differ from these estimates and assumptions.
Regulatory Accounting
The TVA Board is authorized by the TVA Act to set rates for power sold to customers; thus, TVA is "self-regulated." Additionally, TVA's regulated rates are designed to recover its costs of providing electricity. In view of demand for electricity and the level of competition, TVA has assumed 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
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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 of costs that are not likely to be incurred or deferral of gains that will be credited to customers in future periods. The timeframe over which the regulatory assets are recovered from customers or regulatory liabilities are credited to customers is subject to annual TVA Board approval. At September 30, 2019, TVA had $8.9 billion of Regulatory assets and $150 million of Regulatory liabilities.
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.
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 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.
TVA does not believe there is a reasonable likelihood that there will be a material change in the estimates or assumptions used to record regulatory assets and liabilities. If future recovery of regulatory assets ceases to be probable, or any of the other factors described herein cease to be applicable, TVA would be required to write off these costs and recognize them in net income or other comprehensive income.
Asset Retirement Obligations
TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets. These obligations relate to TVA's generating facilities, including coal-fired, nuclear, hydroelectric, and natural gas and/or oil-fired. They also pertain to coal ash impoundments, transmission facilities, and other property-related assets. Activities involved with the retirement of these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site restoration. TVA periodically reviews its estimated asset retirement obligation ("ARO") liabilities. Revisions to the ARO estimates are made whenever factors indicate that the timing or amounts of estimated cash flows have changed. Any change to an ARO liability is recognized prospectively as an equivalent increase or decrease in the carrying value of the capitalized asset. 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.
Nuclear Decommissioning. Utilities that own and operate nuclear plants are required to recognize a liability for legal obligations related to nuclear decommissioning. An equivalent amount is recorded as an increase in the carrying value of the capitalized asset and allocated to a regulatory asset over the useful life of the capitalized asset. The initial obligation is measured at its estimated fair value using various judgments and assumptions. Fair value is developed using an expected present value technique that is based on assumptions of market participants and that considers estimated retirement costs in current period dollars that are inflated to the anticipated decommissioning date and then discounted back to the date the ARO was incurred. Decommissioning cost studies are updated for each of TVA's nuclear units at least every five years. Changes in assumptions and estimates included within the calculations of the value of the AROs could result in significantly different results than those identified and recorded in the financial statements.
At September 30, 2019, the estimated future nuclear decommissioning cost recognized in the financial statements was $3.1 billion and was included in AROs, and the unamortized regulatory asset related to nuclear decommissioning ARO costs of $868 million was included in Regulatory assets.
The following key assumptions can have a significant effect on estimates related to the nuclear decommissioning costs reported in TVA's nuclear ARO liability:
Timing and Method – In projecting decommissioning costs, two assumptions must be made to estimate the timing of plant decommissioning. First, the date of the plant's retirement must be estimated. At Browns Ferry and Sequoyah, the estimated retirement date is based on the unit with the longest license period remaining. At Watts Bar, the estimated retirement date is based on each unit's license period. Second, an assumption must be made on the timing of the decommissioning. 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 that radioactive contamination 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
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nuclear decommissioning estimates on site-specific cost studies, which are updated for each of TVA's nuclear units at least every five years. Changes in probabilities ascribed to the assumptions or the timing of decommissioning can significantly change the present value of TVA's obligations.
Cost Estimates – There is limited experience with actual decommissioning of large nuclear facilities. Changes in technology and experience as well as changes in regulations regarding nuclear decommissioning could cause cost estimates to change significantly. TVA's cost studies assume current technology and regulations.
Cost Escalation Rate – TVA uses expected inflation rates over the remaining timeframe until the costs are expected to be incurred to estimate the amount of future cash flows required to satisfy TVA's decommissioning obligations.
Discount Rate – TVA uses its incremental borrowing rate over a period consistent with the remaining timeframe until the costs are expected to be incurred to calculate the present value of the weighted estimated cash flows required to satisfy TVA's decommissioning obligations.
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. A 10 percent change in TVA's ARO for nuclear decommissioning cost at September 30, 2019, would have affected the liability by approximately $314 million.
Non-Nuclear Decommissioning. At September 30, 2019, the estimated future non-nuclear decommissioning cost recognized in the financial statements was $2.5 billion and was included in AROs, and the unamortized regulatory asset related to non-nuclear decommissioning ARO costs of $1.7 billion was included in Regulatory assets. 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 predicting how costs will escalate with inflation. These costs are predominantly CCR and asbestos removal. CCR removal is primarily closure-in-place except for specific ponds located at Allen and Gallatin. Asbestos removal is based on cost per square foot. The following key assumptions can have a significant effect on estimates related to the non-nuclear decommissioning costs:
Timing and Method – In projecting non-nuclear decommissioning costs, the date of the asset's retirement must be estimated. In instances where the retirement of a specific asset will precede the retirement of the generating plant, the anticipated retirement date of the specific asset is used. Additionally, TVA expects to incur certain ongoing costs subsequent to the initial asset retirement. TVA develops its cost estimates based on likelihood of decommissioning method where options exist in fulfilling legal obligations (e.g. closure-in-place or closure-by-removal for coal ash impoundments). The decommissioning method is determined based on several factors including available technologies, environmental studies, cost factors, resource availability, and timing requirements. As these factors are considered and decommissioning methods are determined, the detailed project schedules and estimates are adjusted. During 2016, TVA management updated its non-nuclear plant closure method assumption from a maintain-in-place method to a plant demolition method. See Note 8 — Regulatory Assets and Liabilities — Non-Nuclear Decommissioning Costs.
Technology and Regulation – Changes in technology and experience as well as changes in regulations regarding non-nuclear decommissioning could cause cost estimates to change significantly. TVA's cost estimates generally assume current technology and regulations. In April 2015, the EPA published its final rule governing CCR, which regulates landfill and impoundment location, design, and operations; dictates certain pond-closure conditions; and establishes groundwater monitoring and closure and post-closure standards. As a result of this ruling, in 2015 TVA made revisions to the assumptions and estimates used to calculate its CCR AROs. TVA continues to evaluate the impact of the rule on its operations, including cost and timing estimates of related projects. As a result, further adjustments to its ARO liabilities may be required as estimates are refined.
Cost Escalation Rate – TVA uses expected inflation rates over the remaining timeframe until the costs are expected to be incurred to estimate the amount of future cash flows required to satisfy TVA's decommissioning obligations.
Discount Rate – TVA uses its incremental borrowing rate over a period consistent with the remaining timeframe until the costs are expected to be incurred to calculate the present value of the weighted estimated cash flows required to satisfy TVA's decommissioning obligations.
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 the discount or escalation rates, changes in regulatory requirements, changes in technology, and changes in the cost of labor, materials, and equipment. A 10 percent change in TVA's ARO for non-nuclear decommissioning costs at September 30, 2019, would have affected the liability by approximately $243 million.
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Gallatin Coal Combustion Residuals. 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.
Pension and Other Post-Retirement Benefits
TVA sponsors a defined benefit pension plan that is qualified under section 401(a) of the Internal Revenue Code and covers substantially all of its full-time annual employees hired prior to July 1, 2014. TVARS, a separate legal entity governed by its own board of directors, administers the qualified defined benefit pension plan. TVA also provides a Supplemental Executive Retirement Plan ("SERP") to certain executives in critical positions, which provides supplemental pension benefits tied to compensation levels that exceed limits imposed by IRS rules applicable to the qualified defined benefit pension plan. Additionally, TVA provides post-retirement health care benefits for most of its full-time employees who reach retirement age while still working for TVA.
TVA's pension and other post-retirement benefits contain uncertainties because they require management to make certain assumptions related to TVA's cost to provide these benefits. Numerous factors are considered including the provisions of the plans, changing employee demographics, various actuarial calculations, assumptions, and accounting mechanisms. The most significant of these factors are discussed below.
Expected Return on Plan Assets. 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. Based upon review of the current plan's asset target allocation mix, capital market outlooks, and the most recent studies, TVA management maintained its 6.75 percent expected long-term rate of return on plan assets assumption, which will be used to calculate the 2020 net periodic pension cost.
TVA recognizes the impact of asset performance on pension expense over a three-year phase-in period through a market-related value of assets calculation. The market-related value of assets recognizes investment gains and losses over a three-year period and is used in calculating expected return on plan assets and net gain or loss for pension cost determination.
A higher expected rate of return assumption decreases the net periodic pension benefit costs, whereas a lower expected rate of return assumption increases the net periodic pension benefit cost. The plan's actual rate of return for 2019 was 4.99 percent compared to the assumption of 6.75 percent. The difference between the expected and actual return on plan assets resulted in an actuarial loss of $88 million that is recognized as an increase in the related regulatory asset and an increase in the pension benefit obligation at September 30, 2019.
Discount Rate. TVA's discount rates are derived by identifying a theoretical settlement portfolio of high quality corporate bonds of Aa quality or higher sufficient to provide for the projected benefit payments. The model matches the present value of the projected benefit payments to the market value of the theoretical settlement bond portfolio with any resulting excess funds presumed to be reinvested and used to meet successive year benefit payments. A single equivalent discount rate is determined to align the present value of the required cash flow with the value of the bond portfolio. The resulting discount rates are reflective of both the current interest rate and the distinct liability of the pension and post-retirement benefit plans.
The discount rate is somewhat volatile because it is determined based upon the prevailing rate as of the measurement date. A higher discount rate decreases the plan obligations and correspondingly decreases the net periodic pension and net post-retirement benefit costs for those plans where actuarial losses are being amortized. Alternatively, a lower discount rate increases net periodic pension and net periodic post-retirement benefit costs. The discount rates used to determine the pension and post-retirement benefit obligations were 3.20 percent and 3.30 percent, respectively, at September 30, 2019.
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 2024. 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. This reset of the health cost trend rate assumptions resulted in a $24 million net decrease in the post-retirement obligation at September 30, 2019.
Cost of Living Adjustments. Cost of living adjustments ("COLAs") are an increase in the benefits for eligible retirees to help maintain the purchasing power of benefits as consumer prices increase. This assumption is based on the long-term expected future rate of inflation based on the capital market outlooks, economic forecasts, and the Federal Reserve policy. See
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Note 21 — Benefit Plans — Plan Assumptions — Cost of Living Adjustment for further discussion on the calculation of the COLA. The actual COLA for CY 2019 was 2.21 percent, and the COLA assumption for CY 2020 and thereafter is 2.00 percent. A higher COLA increases the pension benefit obligation whereas a lower assumption decreases the obligation. 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.
Sensitivity to Changes in Key Assumptions
The following tables illustrate the estimated effects of changing certain of the critical actuarial assumptions discussed above, while holding all other assumptions constant and excluding any impact for unamortized actuarial gains and losses:

Sensitivity to Certain Changes in Pension Assumptions At September 30, 2019
Actuarial Assumption |  | Current Assumption |  | Change in Assumption |  | Impact
Effect on 2019 pension expense: |  |  |  |  |  |
Discount rate |  | 4.35 | % |  | (0.25 | )% |  | $ | 16 |
Expected return on assets |  | 6.75 | % |  | (0.25 | )% |  | 14 |
COLA |  | 2.00 | % |  | 0.25 | % |  | 27 |
Effect on benefit obligation |  |  |  |  |  |
Discount rate |  | 3.20 | % |  | (0.25 | )% |  | 399 |
COLA |  | 2.00 | % |  | 0.25 | % |  | 261 |

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 | )

Contributions. The minimum pension contribution for 2019 was $300 million and was paid in twelve monthly installments. TVA made contributions of $7 million to the SERP and $36 million, net of rebates and subsidies received, to the unfunded other post-retirement benefit plans. TVA expects to contribute $300 million to TVARS, $5 million to the SERP, and $29 million to the other post-retirement benefit plans in 2020.
Accounting Mechanisms. In accordance with current accounting guidance, TVA utilizes a number of accounting mechanisms that reduce the volatility of reported pension expense. Differences between actuarial assumptions and actual plan results are deferred and amortized into period expense only when the accumulated differences exceed 10 percent of the greater of the projected benefit obligation or the market-relative value of plan assets. If necessary, the excess is amortized over the
average future expected working lifetime of participants expected to receive benefits, which is approximately 10 years for the pension plan and 12 years for the post-retirement plan. Additionally, TVA recognizes pension costs as regulatory assets 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. Furthermore, 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 a plan change is amortized over the average remaining service period of participating employees expected to receive benefits under the plans. The pension and post-retirement plans currently have prior service costs/(credits) from plan changes made in 2009, 2010, 2016, 2018, and 2019 with remaining amortization periods of one to 10 years.
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Fair Value Measurements
Investments
Investment Funds. Investments classified as trading consist of amounts held in the Nuclear Decommissioning Trust ("NDT"), Asset Retirement Trust ("ART"), SERP, and Deferred Compensation Plan ("DCP"). These assets are generally measured at fair value based on quoted market prices or other observable market data such as interest rate indices. These investments are primarily U.S. and international equities, real estate investment trusts, fixed income investments, high-yield fixed income investments, U.S. Treasury Inflation-Protected Securities, treasuries, currencies, derivative instruments, and other investments. TVA has classified all of these trading securities as either Level 1, Level 2, or Investments measured at net asset value. See Note 16 — Fair Value Measurements — Valuation Techniques for a discussion of valuation levels of the investments.
Plan Investments. TVA's qualified benefit pension plan is funded with qualified plan assets. These investments are primarily global public equities, private equities, fixed income securities, public real assets, and private real assets. See Note 21 — Benefit Plans — Fair Value Measurements for disclosure of fair value measurements for investments held by TVARS that support TVA's qualified defined benefit pension plan.
Pricing. Prices provided by third-parties for the assets in investment funds and plan investments are subjected to automated tolerance checks by the investment portfolio trustee to identify and avoid, where possible, the use of inaccurate prices. Any such prices identified as outside the tolerance thresholds are reported to the vendor that provided the price. If the prices are validated, the primary pricing source is used. If not, a secondary source price that has passed the applicable tolerance check is used (or queried with the vendor if it is out of tolerance), resulting in either the use of a secondary price, where validated, or the last reported default price, as in the case of a missing price. For monthly valued accounts, where secondary price sources are available, an automated inter-source tolerance report identifies prices with an inter-vendor pricing variance of over two percent at an asset class level. For daily valued accounts, each security is assigned, where possible, an indicative major market index, against which daily price movements are automatically compared. Tolerance thresholds are established by asset class. Prices found to be outside of the applicable tolerance threshold are reported and queried with vendors as described above.
For investment funds, TVA additionally performs its own analytical testing on the change in fair value measurements each period to ensure the valuations are reasonable based on changes in general market assumptions. TVA also performs pricing tests on various portfolios comprised of securities classified in Levels 1 and 2 on a quarterly basis to confirm accuracy of the values received from the investment portfolio trustee. For plan investments, TVARS reviews the trustee's Service Organization Controls report and the pricing policies of the trustee's largest pricing vendor.
Derivatives
TVA has historically entered into various derivative transactions, including commodity option contracts, forward contracts, swaps, swaptions, futures, and options on futures, to manage various market risks. Other than certain derivative instruments included in investment funds, it is TVA's policy to enter into these derivative transactions solely for hedging purposes and not for speculative purposes.
Currency and Interest Rate Derivatives. TVA has three currency swaps and four "fixed for floating" interest rate swaps. The currency swaps protect against changes in cash flows caused by volatility in exchange rates related to outstanding Bonds denominated in British pounds sterling. The currency and interest rate swaps are classified as Level 2 valuations as the rate curves and interest rates affecting the fair value of the contracts are based on observable data. The application of credit valuation adjustments ("CVAs") did not materially affect the fair value of these assets and liabilities at September 30, 2019.
Commodity Contracts. TVA enters into commodity derivatives for coal and natural gas that require physical delivery of the contracted quantity of the commodity. The fair values of these derivative contracts are determined using internal models based on income approaches. TVA develops an overall coal forecast based on widely-used short-term and mid-range market data from an external pricing specialist in addition to long-term internal estimates. To value the volume option component of applicable coal contracts, TVA uses a Black-Scholes pricing model which includes inputs from the overall coal price forecast, contract-specific terms, and other market inputs. Based on the use of certain significant unobservable inputs, these valuations are classified as Level 3 valuations. Additionally, any settlement fees related to early termination of coal supply contracts are included at the contractual amount. The application of CVAs did not materially affect the fair value of these assets and liabilities at September 30, 2019.
TVA maintains policies and procedures to value commodity contracts using what is believed to be the best and most relevant data available. In addition, TVA's risk management group reviews valuations and pricing data. TVA retains independent pricing vendors to assist in valuing certain instruments without market liquidity.
Commodity Derivatives under the Financial Trading Program. TVA established a Financial Trading Program ("FTP") under which it could purchase and sell futures, swaps, options, and similar derivative instruments to hedge its exposure to
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changes in prices of natural gas, fuel oil, coal, and other commodities. 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.
Fair Value Considerations
In determining the fair value of its financial instruments, TVA considers the source of observable market data inputs, liquidity of the instrument, credit risk, and risk of nonperformance of itself or the counterparty to the contract. The conditions and criteria used to assess these factors are described below.
Sources of Market Assumptions. TVA derives its financial instrument market assumptions from market data sources (e.g., CME and Moody's Investors Service, Inc. ("Moody's")). In some cases, where market data is not readily available, TVA uses comparable market sources and empirical evidence to derive market assumptions and determine a financial instrument's fair value.
Market Liquidity. Market liquidity is assessed by TVA based on criteria as to whether the financial instrument trades in an active or inactive market. A financial instrument is considered to be in an active market if the prices are fully transparent to the market participants, the prices can be measured by market bid and ask quotes, the market has a relatively high trading volume, and the market has a significant number of market participants that will allow the market to rapidly absorb the quantity of the assets traded without significantly affecting the market price. Other factors TVA considers when determining whether a market is active or inactive include the presence of government or regulatory control over pricing that could make it difficult to establish a market-based price upon entering into a transaction.
Nonperformance Risk. In determining the potential impact of nonperformance risk, which includes credit risk, TVA 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 derivative instruments that 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 value the investment.
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 a CVA. 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 company. 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.
All derivative instruments are analyzed individually and are subject to unique risk exposures. 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.
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. See Note 15 — Risk Management Activities and Derivative Transactions — Other Derivative Instruments — Collateral for a discussion of collateral related to TVA's derivative liabilities.
New Accounting Standards and Interpretations
See Note 2 — Impact of New Accounting Standards and Interpretations for a discussion of recent accounting standards and pronouncements which were issued by the Financial Accounting Standards Board ("FASB"), became effective for TVA, or were adopted by TVA during the presented periods.
Legislative and Regulatory Matters
TVA continues to monitor how regulatory agencies are interpreting and implementing the provisions of the Dodd-Frank Wall Street Reform and Consumer Protection Act, which was enacted in July 2010. As a result, TVA has become subject to recordkeeping, reporting, and reconciliation requirements related to its derivative transactions. In addition, depending on how regulatory agencies interpret and implement the provisions, TVA's hedging costs may increase, and TVA may have to post additional collateral and margin in connection with its derivative transactions.
For a discussion of environmental legislation and regulation, see Item 1, Business — Environmental Matters.
TVA does not engage, and does not control any entity that is engaged, in any activity listed under Section 13(r) of the Securities Exchange Act of 1934 (the "Exchange Act"), which requires certain issuers to disclose certain activities relating to Iran
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involving the issuer and its affiliates. Based on information supplied by each such person, none of TVA's directors and executive officers are involved in any such activities. While TVA is an agency and instrumentality of the U.S., TVA does not believe its disclosure obligations, if any, under Section 13(r) extend to the activities of any other departments, divisions, or agencies of the U.S.
Environmental Matters
See Item 1, Business — Environmental Matters, which discussion is incorporated by reference into this Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
Legal Proceedings
From time to time, TVA is a party to or otherwise involved in Legal Proceedings that have arisen in the ordinary course of conducting its activities, as a result of catastrophic events or otherwise. As of September 30, 2019, TVA had accrued approximately $14 million with respect to Legal Proceedings. No assurance can be given that TVA will not be subject to significant additional claims and liabilities. If actual liabilities significantly exceed the estimates made, TVA's results of operations, liquidity, and financial condition could be materially adversely affected.
For a discussion of certain current material Legal Proceedings, see Note 22 — Commitments and Contingencies — Legal Proceedings, which discussions are incorporated into this Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
Risk Management Activities
TVA is exposed to various market risks. These market risks include risks related to commodity prices, investment prices, interest rates, currency exchange rates, inflation, and counterparty credit and performance risk. To help manage certain of these risks, TVA has entered into various derivative transactions, including 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. See Note 15 — Risk Management Activities and Derivative Transactions.
Risk Governance
The Enterprise Risk Council ("ERC") is responsible for the highest level of risk oversight at TVA and is also responsible for communicating enterprise-wide risks with policy implications to the TVA Board or a designated TVA Board committee. The ERC is comprised of the Enterprise Leadership Team ("ELT") and the Chief Risk Officer ("CRO") who acts as Chair. ERC members may invite additional attendees to meetings as non-voting participants. The ERC has also established subordinate committees, consisting of business unit leaders, to assist in the oversight of fuel and power procurement, DER programs and products, and general risk management.
TVA has a designated Enterprise Risk Management ("ERM") organization within its Financial Services organization responsible for (1) establishing enterprise risk management policies and guidelines, (2) developing an enterprise risk profile aligned with TVA's strategic objectives, (3) performing annual risk assessments across all TVA business units, (4) monitoring and reporting on identified enterprise risks and emerging risks, (5) facilitating enterprise risk discussions with the risk subject matter experts across the organization and at the ERC and TVA Board levels, and (6) developing and improving TVA's risk awareness culture. TVA has cataloged major short-term and long-term enterprise level risks across the organization. A discussion of significant risks is presented in Item 1A, Risk Factors.
Commodity Price Risk
TVA is exposed to effects of market fluctuations in the price of commodities that are critical to its operations, including electricity, coal, and natural gas. The magnitude of exposure to these risks is influenced by many factors including contract terms and market liquidity. TVA's commodity price risk is substantially mitigated by its cost-based rates, including its total fuel cost adjustment, and long-term fixed price commodity contracts.
TVA manages risk with commodity contract derivatives for both coal and natural gas that require physical delivery of the contracted quantity. A hypothetical 10 percent decline in the market price of coal on September 30, 2019 and 2018, would have resulted in decreases of approximately $34 million and $63 million, respectively, in the fair value of TVA's coal derivative instruments at these dates. A hypothetical 10 percent decline in the market price of natural gas on September 30, 2019 and 2018, would have resulted in decreases of approximately $79 million and $102 million, respectively, in the fair value of TVA's natural gas derivative instruments at these dates.
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Investment Price Risk
TVA's investment price risk relates primarily to investments in TVA's NDT, ART, pension fund, SERP, and DCP.
Nuclear Decommissioning Trust. The NDT is generally designed to achieve a return in line with overall equity and debt market performance. The assets of the trust are invested in debt and equity securities, private partnerships, and certain derivative instruments including forwards, futures, options, and swaps, and through these investments the trust has exposure to U.S. equities, international equities, real estate investment trusts, natural resource equities, high-yield debt, domestic debt, U.S. Treasury Inflation-Protected Securities ("TIPS"), treasuries, private real assets, private equity, and private credit strategies. At September 30, 2019 and 2018, an immediate 10 percent decrease in the price of the investments in the trust would have reduced the value of the trust by $211 million and $205 million, respectively.
Asset Retirement Trust. The ART is presently invested to achieve a return in line with overall equity and debt market performance. The assets of the trust are invested in debt and equity securities, private partnerships, and certain derivative instruments including options, and through these investments the trust has exposure to U.S. equities, real estate investment trusts, natural resource equities, high-yield debt, domestic debt, TIPS, treasuries, private real assets, private equity, and private credit strategies. At September 30, 2019 and 2018, an immediate 10 percent decrease in the price of the investments in the trust would have reduced the value of the trust by $77 million and $71 million, respectively.
Qualified Pension Plan. 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 asset investments. 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 the system'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 these 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, an immediate 10 percent decrease in the value of the net assets of the fund would have reduced the value of the fund by approximately $798 million and $800 million, respectively.
Supplemental Executive Retirement Plan. The SERP is a non-qualified defined benefit pension plan similar to those typically found in other companies in TVA's peer group and is provided to selected employees of TVA. TVA's SERP was created to recruit and retain key executives. The plan is designed to provide a competitive level of retirement benefits in excess of the limitations on contributions and benefits imposed by TVA's qualified defined benefit plan and Internal Revenue Code Section 415 limits on qualified retirement plans. The SERP currently targets an asset allocation policy for its plan assets of 64 percent equity securities, which includes U.S. and non-U.S. equities, and 36 percent fixed income securities. The SERP plan assets are presently invested to achieve a return in line with overall equity and debt market performance. At September 30, 2019 and 2018, an immediate 10 percent decrease in the value of the SERP investments would have reduced the value of the investments by $6 million and $7 million, respectively.
Deferred Compensation Plan. The DCP is designed to provide participants with the ability to defer compensation until employment with TVA ends. The plan assists in the recruitment of top executive talent for TVA. As in other corporations, deferred compensation can be an integral part of a total compensation package. Assets currently include deferral balances. The default return on investment of the accounts is interest calculated based on the composite rate of all marketable U.S. Treasury issues. Executives may alternatively choose to have their balances adjusted based on the return of certain mutual funds. At both September 30, 2019 and 2018, an immediate 10 percent decrease in the value of the deferred compensation accounts would have reduced the value of the accounts by $3 million.
Interest Rate Risk
TVA's interest rate risk is related primarily to its short-term investments, short-term debt, long-term debt, and interest rate derivatives.
Investments. At September 30, 2019, TVA had $299 million of cash and cash equivalents, and the average balance of cash and cash equivalents for 2019 was $336 million. The average interest rate that TVA received on its short-term investments during 2019 was 2.40 percent. If the rates of interest that TVA received on its short-term investments during 2019 were 1.40 percent, TVA would have received approximately $3 million less in interest from its short-term investments. At September 30, 2018, TVA had $299 million of cash and cash equivalents, and the average balance of cash and cash equivalents for 2018 was $348 million. The average interest rate that TVA received on its short-term investments during 2018 was 1.60 percent. If the rates that TVA received on its short-term investments during 2018 were 0.60 percent, TVA would have received approximately $3 million less in interest from its short-term investments. In addition to affecting the amount of interest that TVA receives from
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its short-term investments, changes in interest rates could affect the value the investments in its pension plan, ART, NDT, SERP, and DCP. See Risk Management Activities — Investment Price Risk above.
Short-Term Debt. At September 30, 2019, TVA's short-term borrowings were $922 million, and the current maturities of long-term debt were $1.1 billion. Based on TVA's interest rate exposure at September 30, 2019, an immediate one percentage point increase in interest rates would have resulted in an increase of $20 million in TVA's short-term interest expense. At September 30, 2018, TVA's short-term borrowings were $1.2 billion, and the current maturities of long-term debt were $1.1 billion. Based on TVA's interest rate exposure at September 30, 2018, an immediate one percentage point increase in interest rates would have resulted in an increase of $23 million in TVA's short-term interest expense.
Long-Term Debt. At September 30, 2019 and 2018, the interest rates on all of TVA's outstanding long-term debt were fixed (or subject only to downward adjustment under certain conditions). Accordingly, an immediate one percentage point increase in interest rates would not have affected TVA's interest expense associated with its long-term debt. When TVA's long-term debt matures or is redeemed, however, TVA typically refinances debt in whole or in part by issuing additional debt. Accordingly, if interest rates are high when TVA issues this additional debt, TVA's cash flows, results of operations, and financial condition may be adversely affected. This risk is somewhat mitigated by the fact that TVA's debt portfolio is diversified in terms of maturities and has a long average life. At September 30, 2019 and 2018, the average life of TVA's debt portfolio was 16.1 years and 16.3 years, respectively. A schedule of TVA's debt maturities is contained in Note 13 — Debt and Other Obligations — Debt Outstanding.
Interest Rate Derivatives. Changes in interest rates also affect the mark-to-market valuation of TVA's interest rate derivatives. See Note 15 — Risk Management Activities and Derivative Transactions — Derivatives Not Receiving Hedge Accounting Treatment — Interest Rate Derivatives. TVA had four interest rate swaps outstanding at September 30, 2019 and September 30, 2018. Net unrealized gains and losses on these instruments are reflected on TVA's Consolidated Balance Sheets in a regulatory asset account, and realized gains and losses are reflected in earnings. Based on TVA's interest rate exposure at September 30, 2019 and 2018, an immediate one-half percentage point decrease in interest rates would have increased the interest rate swap liabilities by $253 million and $196 million, respectively.
London Interbank Offered Rate. TVA has four "fixed for floating" interest rate swaps related to outstanding Bonds, and receives periodic payments under these swaps based on the floating London Interbank Offered Rate ("LIBOR") benchmark rate. TVA may also have additional contracts that could be impacted. LIBOR is expected to be discontinued after 2021. Various alternatives for LIBOR are being evaluated by market participants, with the Secured Overnight Financing Rate being the most widely-adopted alternative thus far. TVA may face risks related to the viability of an alternative benchmark over the remaining terms of its current contracts, or over the terms of any future contracts that rely on the benchmark rate.
Currency Exchange Rate Risk
Over the next several years, TVA plans to spend a significant amount of capital on clean air projects, capacity expansion, and other projects. A portion of this amount may be spent on contracts that are denominated in one or more foreign currencies. Additionally, TVA's three issues of Bonds denominated in British pounds sterling are hedged by currency swap agreements. The value of the U.S. dollar compared with other currencies has fluctuated widely in recent years, including fluctuations in the U.S. dollar to British pound sterling exchange rate primarily driven by the "BREXIT" vote for the United Kingdom to leave the European Union. If not effectively managed, foreign currency exposure could negatively impact TVA's counterparty risk, cash flows, results of operations, and financial condition.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Quantitative and qualitative disclosures about market risk are reported in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Risk Management Activities, which discussion is incorporated by reference into this Item 7A, Quantitative and Qualitative Disclosures About Market Risk.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
TENNESSEE VALLEY AUTHORITY
CONSOLIDATED STATEMENTS OF OPERATIONS
For the years ended September 30
(in millions)

| 2019 |  | 2018 |  | 2017
Operating revenues |  |  |  |  |
Revenue from sales of electricity | $ | 11,159 |  |  | $ | 11,075 |  |  | $ | 10,586 |
Other revenue | 159 |  |  | 158 |  |  | 153 |
Total operating revenues | 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 |
Other net periodic benefit cost | 258 |  |  | 256 |  |  | 758 |
Interest expense | 1,198 |  |  | 1,243 |  |  | 1,346 |
Net income (loss) | $ | 1,417 |  |  | $ | 1,119 |  |  | $ | 685 |

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TENNESSEE VALLEY AUTHORITY
CONSOLIDATED BALANCE SHEETS
At September 30
(in millions)

ASSETS
| 2019 |  | 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 |
The accompanying notes are an integral part of these consolidated financial statements.

81

TENNESSEE VALLEY AUTHORITY
CONSOLIDATED BALANCE SHEETS
At September 30
(in millions)

LIABILITIES AND PROPRIETARY CAPITAL
| 2019 |  | 2018
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 | — |  |  | 10 |
Regulatory liabilities | 150 |  |  | 187 |
Short-term debt, net | 922 |  |  | 1,216 |
Current maturities of power bonds | 1,030 |  |  | 1,032 |
Current maturities of long-term debt of variable interest entities | 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 |
Regulatory liabilities | — |  |  | 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 | — |  |  | 23 |
Total long-term debt, net | 20,183 |  |  | 21,307 |
Total liabilities | 38,842 |  |  | 38,384 |
Commitments and contingencies (Note 22) |  |  |
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 |
The accompanying notes are an integral part of these consolidated financial statements.

82

TENNESSEE VALLEY AUTHORITY
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
For the years ended September 30
(in millions)

| 2019 |  | 2018 |  | 2017
Net income (loss) | $ | 1,417 |  |  | $ | 1,119 |  |  | $ | 685 |
Other comprehensive income (loss) |  |  |  |  |
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 |
The accompanying notes are an integral part of these consolidated financial statements.

83

TENNESSEE VALLEY AUTHORITY
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the years ended September 30
(in millions)

| 2019 |  | 2018 |  | 2017
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(1) | 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 | )
Other regulatory amortization and deferrals | 261 |  |  | 2 |  |  | 143 |
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 | )
Cash flows from financing activities |  |  |  |  |  |  |  |
Long-term debt |  |  |  |  |  |  |  |
Issues of power bonds | — |  |  | 998 |  |  | 999 |
Redemptions and repurchases of power bonds | (1,035 | ) |  | (1,731 | ) |  | (1,558 | )
Payments on debt of variable interest entities | (38 | ) |  | (36 | ) |  | (35 | )
Redemptions of notes payable | (46 | ) |  | (53 | ) |  | (27 | )
Short-term debt issues (redemptions), net | (294 | ) |  | (782 | ) |  | 592 |
Payments on leases and leasebacks | (43 | ) |  | (42 | ) |  | (136 | )
Financing costs, net | — |  |  | (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 | — |  |  | 11 |  |  | 1 |
Cash, cash equivalents, and restricted cash at beginning of year | 322 |  |  | 311 |  |  | 310 |
Cash, cash equivalents, and restricted cash at end of year | $ | 322 |  |  | $ | 322 |  |  | $ | 311 |
The accompanying notes are an integral part of these consolidated financial statements.

Note
(1) Including amortization of debt issuance costs and premiums/discounts.
84

TENNESSEE VALLEY AUTHORITY
CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL
For the years ended September 30
(in millions)

| Power Program Appropriation Investment |  | Power Program Retained Earnings |  | Nonpower Programs Appropriation Investment, Net |  | Accumulated Other Comprehensive Income (Loss) |  | Total
Balance at September 30, 2016 | $ | 258 |  |  | $ | 7,594 |  |  | $ | 580 |  |  | $ | (12 | ) |  | $ | 8,420 |
Net income (loss) | — |  |  | 693 |  |  | (8 | ) |  | — |  |  | 685 |
Total other comprehensive income (loss) | — |  |  | — |  |  | — |  |  | 33 |  |  | 33 |
Return on power program appropriation investment | — |  |  | (5 | ) |  | — |  |  | — |  |  | (5 | )
Balance at September 30, 2017 | $ | 258 |  |  | $ | 8,282 |  |  | $ | 572 |  |  | $ | 21 |  |  | $ | 9,133 |
Net income (loss) | — |  |  | 1,127 |  |  | (8 | ) |  | — |  |  | 1,119 |
Total other comprehensive income (loss) | — |  |  | — |  |  | — |  |  | 36 |  |  | 36 |
Return on power program appropriation investment | — |  |  | (5 | ) |  | — |  |  | — |  |  | (5 | )
Balance at September 30, 2018 | $ | 258 |  |  | $ | 9,404 |  |  | $ | 564 |  |  | $ | 57 |  |  | $ | 10,283 |
Net income (loss) | — |  |  | 1,425 |  |  | (8 | ) |  | — |  |  | 1,417 |
Total other comprehensive income (loss) | — |  |  | — |  |  | — |  |  | (69 | ) |  | (69 | )
Return on power program appropriation investment | — |  |  | (6 | ) |  | — |  |  | — |  |  | (6 | )
Balance at September 30, 2019 | $ | 258 |  |  | $ | 10,823 |  |  | $ | 556 |  |  | $ | (12 | ) |  | $ | 11,625 |
The accompanying notes are an integral part of these consolidated financial statements.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Dollars in millions except where noted)

Note | Page No.
1 |  | Summary of Significant Accounting Policies | 86
2 |  | Impact of New Accounting Standards and Interpretations | 92
3 |  | Accounts Receivable, Net | 95
4 |  | Inventories, Net | 95
5 |  | Net Completed Plant | 96
6 |  | Plant Closures | 96
7 |  | Other Long-Term Assets | 97
8 |  | Regulatory Assets and Liabilities | 98
9 |  | Asset Acquisitions | 101
10 |  | Variable Interest Entities | 101
11 |  | Other Long-Term Liabilities | 103
12 |  | Asset Retirement Obligations | 104
13 |  | Debt and Other Obligations | 105
14 |  | Accumulated Other Comprehensive Income (Loss) | 111
15 |  | Risk Management Activities and Derivative Transactions | 111
16 |  | Fair Value Measurements | 116
17 |  | Revenue | 121
18 |  | Proprietary Capital | 125
19 |  | Other Income (Expense), Net | 126
20 |  | Supplemental Cash Flow Information | 126
21 |  | Benefit Plans | 126
22 |  | Commitments and Contingencies | 140
23 |  | Related Parties | 145
24 |  | Unaudited Quarterly Financial Information | 146
25 |  | Subsequent Events | 147

1. Summary of Significant Accounting Policies
General
The Tennessee Valley Authority ("TVA") is a corporate agency and instrumentality of the United States ("U.S.") that was created in 1933 by federal legislation in response to a proposal by President Franklin D. Roosevelt. TVA was created to, among other things, improve navigation on the Tennessee River, reduce the damage from destructive flood waters within the Tennessee River system and downstream on the lower Ohio and Mississippi Rivers, further the economic development of TVA's service area in the southeastern U.S., and sell the electricity generated at the facilities TVA operates.
Today, TVA operates the nation's largest public power system and supplies power in most of Tennessee, northern Alabama, northeastern Mississippi, and southwestern Kentucky and in portions of northern Georgia, western North Carolina, and southwestern Virginia to a population of 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
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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
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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
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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
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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 (percent)
| 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 —
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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.
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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.
2. 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.

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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. TVA recognizes revenue when it satisfies a performance obligation by transferring control to the customer. For the generation and transmission of electricity, this is generally at the time the power is delivered to a metered customer delivery point for a customer's consumption or distribution. As a result, revenues from power sales are recorded as electricity is delivered to customers. TVA utilized certain practical expedients including applying the guidance to open contracts at the date of adoption, applying the guidance to a portfolio of contracts with similar characteristics, and recognizing revenue in the amount for which it has the right to invoice. As a result of adoption of the standard, TVA did not have a cumulative-effect adjustment to proprietary capital.
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.

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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. TVA has elected to apply the following practical expedients:
| 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.

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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.

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.
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 |

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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.
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.
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7. Other Long-Term Assets
The table below summarizes the types and amounts of TVA's other long-term assets:

Other Long-Term Assets 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.
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8. 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
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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
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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.
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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.
9. 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.
10. 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.
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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.
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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.
11. 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
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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.
12. 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.
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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.
13. 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.
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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
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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.
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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 |

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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.
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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.
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14. 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.
15. 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 Hedging Instrument |  | 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.
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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 Realized gains and losses are recognized in interest expense when incurred during the settlement period |  | $ | (79 | ) |  | $ | (89 | )
Commodity derivatives under FTP |  | 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 Realized gains and losses are recognized in fuel expense or purchased power expense when the related commodity is used in production |  | — |  |  | (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 accrued liabilities $(56); Other long-term liabilities $(822)
$476 million notional | (498 | ) |  | Accounts payable and accrued liabilities $(24); Other long-term liabilities $(474) |  | (317 | ) |  | Accounts payable and accrued liabilities $(20); Other long-term liabilities $(297)
$42 million notional | (5 | ) |  | Accounts payable and accrued liabilities $(2); Other long-term liabilities $(3) |  | (4 | ) |  | Accounts payable and accrued liabilities $(1); Other long-term liabilities $(3)
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)

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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 | )

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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.
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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
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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.
16. 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
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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
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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.
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Fair Value Measurements At September 30, 2018
| 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 | $ | 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 (Level 1) |  | Significant Other Observable Inputs (Level 2) |  | Significant Unobservable Inputs (Level 3) |  | 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 | )

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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

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Other Financial Instruments Not Recorded at Fair Value
TVA uses the methods and assumptions described below to estimate the fair value of each significant class of financial 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 Amount |  | Fair Value |  | Carrying Amount |  | 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.
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.
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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. The amount of revenue is based on contractual prices approved by the TVA Board. Customers are invoiced monthly for power delivered as measured by meters located at the delivery points. The net transaction price is offset by certain credits available to customers that are known at the time of billing. Credits are designed to achieve objectives of the TVA Act and include items such as hydro preference credits for residential customers of LPCs, economic development credits to promote growth in the Tennessee Valley, wholesale bill credits to maintain long-term partnerships with LPCs, and 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.
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.
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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.
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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 (in millions) |  | 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.
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18. 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.
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19. 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.
20. 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.
21. 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
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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
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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.
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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 | )

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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.
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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
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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.
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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 | %

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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.
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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.
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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 |

The following descriptions of the valuation methods and assumptions used by the pension plan to estimate the fair value of investments apply to investments held directly by the pension plan. Third-party pricing vendors provide valuations for investments held by the pension plan in most instances, except for commingled, private credit, private equity, and private real estate funds which are priced at net asset values established by the investment managers. In instances where pricing is determined to be based on unobservable inputs, a Level 3 classification has been assigned. Certain securities priced by the investment manager using a proprietary fair value model with unobservable inputs have been classified as Level 3.
Equity and Preferred Securities. Investments listed on either a national or foreign securities exchange or traded in the over-the-counter National Market System are generally valued each business day at the official closing price (typically the last reported sale price) on the exchange on which the security is primarily traded and are classified as Level 1. Equity securities, including common stocks and preferred securities, classified as Level 2 may have been priced by dealer quote or using assumptions based on observable market data, such as yields on bonds from the same issuer or industry. Certain securities priced by the investment manager using unobservable inputs have been classified as Level 3.
Corporate Debt Securities. Corporate bonds are valued based upon recent bid prices or the average of recent bid and asked prices when available (Level 2 inputs) and, if not available, they are valued through matrix pricing models. Matrix pricing, which is a mathematical technique commonly used to price debt securities that are not actively traded, values debt securities without relying exclusively on quoted prices for the specific securities but rather by relying on the securities' relationship to other benchmark quoted securities (Level 2 inputs). Certain securities priced by the investment manager using broker pricing or unobservable inputs have been classified as Level 3.
Mortgage and Asset-Backed Securities. Residential mortgage-backed securities consist of collateralized mortgage obligations ("CMOs") and U.S. pass-through security pools related to government-sponsored enterprises. CMO pricing is typically based on either a volatility-driven, multidimensional, single-cash-flow stream model or an option-adjusted spread model. These models incorporate available market data such as trade information, dealer quotes, market color, spreads, bids, and offers. Pricing for government-sponsored enterprise securities, including the Federal Home Loan Mortgage Corporation, the Federal National Mortgage Association, and the Government National Mortgage Association, is typically based on quotes from the To Be Announced ("TBA") market, which is highly liquid with multiple electronic platforms that facilitate the execution of trading between investors and broker/dealers. Prices from the TBA market are then compared against other live data feeds as well as input obtained directly from the dealer community. Most residential mortgage-backed securities are considered to be priced using Level 2 inputs because of the nature of their market-data-based pricing models. Certain securities priced by vendors using a single broker quote or unobservable inputs have been classified as Level 3.
Debt Securities Issued by U.S. Treasury. For U.S. Treasury securities, fair values reflect the closing price reported in the active market in which the security is traded (Level 1 inputs).
Debt Securities Issued by Foreign Governments. Foreign government bonds and foreign government inflation-linked securities are typically priced based on proprietary discounted cash flow models, incorporating option-adjusted spread features as appropriate. Debt securities issued by foreign governments are classified as Level 2 because of the nature of their market-data-based pricing models. Certain securities priced by the investment manager using broker quotes or unobservable input have been classified as Level 3.
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Debt Securities Issued by State and Local Governments. Debt securities issued by state and local governments are typically priced using market-data-based pricing models, and are therefore classified as Level 2. These pricing models incorporate market data such as quotes, trading levels, spread relationships, and yield curves, as applicable. Certain securities priced using an unobservable input have been classified as Level 3.
Commercial Mortgage-Backed and Asset-Backed Securities. Commercial mortgage-backed and asset-backed securities are typically priced based on a single-cash-flow stream model, which incorporates available market data such as trade information, dealer quotes, market color, spreads, bids, and offers. Because of the market-data-based nature of such pricing models, these securities are typically classified as Level 2. Certain securities priced by investment managers using broker pricing or unobservable inputs have been classified as Level 3.
Commingled Funds. The pension plan invests in commingled funds, which include collective trusts, unit investment trusts, and similar investment funds that predominantly hold debt and/or equity securities as underlying assets. The pension plan's ownership consists of a pro rata share and not a direct ownership of an underlying investment. These commingled funds are valued at their closing net asset values (or unit value) per share as reported by the managers of the commingled funds and as supported by the unit prices of actual purchases and sale transactions occurring as of or close to the financial statement date. These funds have not been classified in the fair value hierarchy in accordance with FASB guidance issued in May 2015.
The pension plan is invested in equity commingled funds, which can be categorized as either passively managed index funds or actively managed funds. The equity index funds seek to track the performance of a particular index by replicating its capitalization and characteristics. Passive fund benchmark indices include the Russell 1000 index, S&P 500 index, MSCI ACWI ex-U.S. index, MSCI ACWI ex-U.S. Small-Cap index, and Dow Jones U.S. Select REIT index. The actively managed equity funds seek to outperform certain equity benchmarks through a combination of fundamental and technical analysis. Active funds select portfolio positions based upon their research.
The pension plan is invested in debt commingled funds, which can be categorized as either passively managed index funds or actively managed funds. The pension plan's debt index fund invests in a diversified portfolio of fixed-income securities and derivatives of varying maturities to replicate the characteristics of the Bloomberg Barclays Capital U.S. Treasury Inflation-Protected Securities ("TIPS") index. The fund seeks to track the total return of the Bloomberg Barclays Capital U.S. TIPS index. The actively managed debt funds seek to outperform certain fixed-income benchmarks through fundamental research and analysis. The funds invest in a diversified portfolio of fixed income securities and derivatives of varying maturities. Varying by strategy, fund objectives include achieving a positive relative total return through active credit selection and providing risk management through desired strategic exposures.
The pension plan is invested in commodity commingled funds, which can be categorized as actively managed funds. The funds seek to outperform certain commodity benchmarks through fundamental research and analysis. The funds invest in a diversified portfolio of commodity securities and derivatives of varying maturities. The objective is to achieve a positive relative return through active security selection.
The pension plan is invested in commingled funds, which invest across multiple asset classes that can be categorized as blended. These funds seek to outperform a passive benchmark through active security selection. The funds invest in securities across equity, fixed income, currency, and commodities. The portfolios employ fundamental, quantitative, and technical analysis.
The pension plan's investments in equity, debt, blended, and commodity commingled funds can generally be redeemed upon notification of the investment managers, with required notice periods varying from same-day to monthly. These investments do not have unfunded commitments.
Institutional Mutual Funds. Investments in institutional mutual funds are valued at prices based on their net asset value. Institutional mutual funds have daily published market prices that represent their net asset value (or unit value) per share and are classified as Level 1.
Cash Equivalents and Other Short-Term Investments and Certificates of Deposit. Cash equivalents and other short-term investments are highly liquid securities with maturities of less than three months and 12 months, respectively. These consist primarily of discount securities such as commercial paper, repurchase agreements, U.S. Treasury bills, and certain agency securities. These securities, as well as certificates of deposit, may be priced at cost, which approximates fair value due to the short-term nature of the instruments. Model based pricing which incorporates observable inputs may also be utilized. These securities are classified as Level 2. Active market pricing may be utilized for U.S. Treasury bills, which are classified as Level 1.
Private Credit Funds. Private credit limited partnerships are reported at net asset values provided by the fund managers. These funds have not been classified in the fair value hierarchy in accordance with FASB guidance issued in May 2015.
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The private credit limited partnerships generally focus on direct lending investments of senior secured first-lien loans to lower-middle market companies and seek to obtain financial returns through high income potential and occasional equity upside. The limited partnerships generally have a term life of five to 10 years and are diversified by sector and industry.
Private Equity Funds. Private equity limited partnerships are reported at net asset values provided by the fund managers. These funds have not been classified in the fair value hierarchy in accordance with FASB guidance issued in May 2015.
The private equity limited partnerships typically make longer-term investments in private companies and seek to obtain financial returns through long-term appreciation based on corporate stewardship, improved operating processes, and financial restructuring which may involve a merger or acquisition. Significant investment strategies include venture capital, buyout, mezzanine or subordinated debt, restructuring or distressed debt, energy infrastructure, and special situations. Venture capital partnerships consist of two main groupings. Early-stage venture capital partnerships invest in businesses still in the conceptual stage where products may not be fully developed and where revenues and/or profits may be several years away. Later-stage venture capital partnerships invest in more mature companies in need of growth or expansion capital. Buyout partnerships provide the equity capital for acquisition transactions either from a private seller or the public, which may represent the purchase of the entire company or a refinancing or recapitalization transaction where equity is invested. Mezzanine or subordinated debt partnerships provide the intermediate capital between equity and senior debt in a buyout or refinancing transaction and typically own a security in the company that carries current interest payments as well as a potential equity interest in the company. Restructuring or distressed debt partnerships purchase opportunities generated by overleveraged or poorly managed companies. Energy infrastructure partnerships acquire essential, long-lived real assets in three main groups. Upstream assets include oil and gas exploration, drilling, and acquisition. Midstream assets include storage, pipelines, gathering, processing, and transportation of energy commodities. Downstream assets include generation, distribution, and transmission facilities. Special situation partnerships include organizations with a specific industry focus not covered by the other private equity subclasses or unique opportunities that fall outside the regular subclasses.
The private equity funds have no investment withdrawal provisions prior to the termination of the partnership. Partnerships generally continue 10 to 12 years after the inception of the fund. The partnerships are subject to two to three one-year extensions at the discretion of the General Partner. Partnerships can generally be dissolved by an 80 percent vote in interest by all limited partners, with some funds requiring the occurrence of a specific event.
Private Real Estate Investments. The pension plan's ownership in private real estate investments consists of a pro rata share and not a direct ownership of the underlying investments. The fair values of the pension plan's private real estate investments are estimated utilizing net asset values provided by the investment managers. These investments have not been classified in the fair value hierarchy in accordance with FASB guidance issued in May 2015. The investment strategies and methodologies utilized by the investment managers to calculate their net asset values are summarized as follows:
The pension plan is invested in limited partnerships that invest in real estate securities, real estate partnerships, and direct real estate properties. This includes investments in office, multifamily, industrial, and retail investment properties in the U.S. and international markets. The investment strategy focuses on distressed, opportunistic, and value-added opportunities. Partnership investments also include mortgage and/or real estate-related fixed-income instruments and related securities. Investments are diversified by property type and geographic location.
The pension plan is invested in a commingled fund which invests across multiple asset classes that can be categorized as blended. The fund seeks to achieve capital appreciation while targeting a specific risk profile. The fund invests in securities across equity, fixed income, currency, and commodities. The portfolio employs fundamental, quantitative, and technical analysis.
Fair value estimates of the underlying investments in these limited partnerships and commingled fund investments are primarily based upon property appraisal reports prepared by independent real estate appraisers within a reasonable amount of time following acquisition of the real estate and no less frequently than annually thereafter. The appraisals are based on one or a combination of three methodologies: cost of reproduction analysis, discounted cash flow analysis, and sales comparison analysis. Pricing for certain investments in mortgage-backed and asset-backed securities is typically based on models that incorporate observable inputs.
The pension plan is invested in a private real estate investment trust formed to make direct or indirect investments in commercial timberland properties. Pricing for these types of investments is based on comprehensive appraisals that are conducted shortly after initial purchase of properties and at three-year intervals thereafter. All appraisals are conducted by third-party timberland appraisal firms. Appraisals are based on either a sales comparison analysis or a discounted cash flow analysis.
Securities Lending Collateral. Collateral held under securities lending arrangements are invested in highly liquid short-term securities, primarily repurchase agreements. The securities are often priced at cost, which approximates fair value due to the short-term nature of the instruments. These securities are classified as Level 2.
Derivatives. The pension plan invests in a variety of derivative instruments. The valuation methodologies for these instruments are as follows:
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Futures. The pension plan enters into futures. The futures contracts are listed on either a national or foreign securities exchange and are generally valued each business day at the official closing price (typically the last reported sales price) on the exchange on which the security is primarily traded. The pricing is performed by third-party vendors. Since futures are priced by an exchange in an active market, they are classified as Level 1.
Options. The pension plan enters into purchased and written options. Options that are listed on either a national or foreign securities exchange are generally valued each business day at the official closing price (typically the last reported sales price) on the exchange on which the security is primarily traded. These options are classified as Level 1. Options traded over the counter and not on exchanges are priced by third-party vendors and are classified as Level 2.
Swaps. The pension plan enters into various types of swaps. Credit default swaps are priced at market using models that consider cash flows, credit curves, recovery rates, and other factors. The pricing is performed by third-party vendors, and in some cases by clearing exchanges. Interest rate swap contracts are priced at market using forward rates derived from the swap curve, and the pricing is also performed by third-party vendors, and in some cases by clearing exchanges. Other swaps such as equity index swaps and variance swaps are priced by third-party vendors using market inputs such as spot rates, yield curves, and volatility. The pension plan's swaps are generally classified as Level 2 based on the observable nature of their pricing inputs.
Foreign currency forwards. The pension plan enters into foreign currency forwards. All commitments are marked to market daily at the applicable translation rates, and any resulting unrealized gains or losses are recorded. Foreign currency forwards are priced by third-party vendors and are classified as Level 2.
Securities Sold Under Agreements to Repurchase. The pension plan enters into contracts to sell securities to a counterparty at a specified price with an agreement to purchase the same or substantially the same security from the same counterparty at a fixed or determinable price at a future date. Securities sold under agreements to repurchase are presented at their contract price which approximates fair value due to their short-term nature. These securities are classified as Level 2. In connection with sales of securities under agreements to repurchase, the counterparties require the pension plan to maintain collateral securities with a fair value that approximates or exceeds the contract amount of the repurchase agreement. These securities are held in government inflation-linked bonds and classified as government debt securities.
The valuation methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Furthermore, while the pension plan believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.
Reclassification. In the September 30, 2018 fair value measurements table, $(108) million of cash equivalents and other short-term investments were reclassified to securities sold under agreements to repurchase.
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.
Contributions. TVA made contributions to the pension plan of $300 million for 2019 and 2018. TVA has committed to make a minimum contribution of $300 million per year through 2036 or until the plan has reached and remained at 100 percent funded status under the actuarial rules applicable to TVARS. TVA made SERP contributions of $7 million and $4 million for 2019 and 2018, respectively. TVA made cash contributions to the other post-retirement benefit plans of $36 million (net of $4 million in rebates) and $25 million (net of $15 million in rebates) for 2019 and 2018, respectively. TVA expects to contribute $300 million to TVARS, $5 million to the SERP, and $29 million to the other post-retirement benefit plans in 2020.
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Other Post-Employment Benefits
Post-employment benefit cost estimates are revised to properly reflect changes in actuarial assumptions made at the end of each year. TVA utilizes a discount rate determined by reference to the U.S. Treasury Constant Maturities corresponding to calculated average durations of TVA's future estimated post-employment claims payments. The use of a 1.68 percent discount rate resulted in the recognition of approximately $59 million in expenses in 2019 and an unpaid benefit obligation of $419 million at September 30, 2019. The use of a 3.05 percent discount rate resulted in the recognition of approximately $(6) million in expenses in 2018 and an unpaid benefit obligation of $339 million at September 30, 2018. The use of a 2.33 percent discount rate resulted in the recognition of approximately $(12) million in expenses in 2017 and an unpaid benefit obligation of $447 million at September 30, 2017.
The increase in the unpaid benefit obligation when comparing 2019 to 2018 was due primarily to the decrease of the discount rate from 3.05 percent in 2018 to 1.68 percent in 2019. The decrease in the unpaid benefit obligation when comparing 2018 to 2017 was due primarily to the increase in the discount rate from 2.33 percent in 2017 to 3.05 percent in 2018. Additional reduction in the obligation was due to a decrease in loss experience and fewer claims.
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 |

22. 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.
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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.

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• | 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.
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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
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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.
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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.
23. 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.
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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 |

24. 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 |

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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.
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Report of Independent Registered Public Accounting Firm
To the Board of Directors of Tennessee Valley Authority
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Tennessee Valley Authority (the Company) as of September 30, 2019 and 2018, the related consolidated statements of operations, comprehensive income (loss), changes in proprietary capital and cash flows for each of the three years in the period ended September 30, 2019, and the related notes (collectively referred to as the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at September 30, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2019, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of September 30, 2019, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework), and our report dated November 14, 2019 expressed an unqualified opinion thereon.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
/s/ Ernst & Young LLP
We have served as the Company’s auditor since 2007
Chattanooga, Tennessee
November 14, 2019
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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
Not applicable.
ITEM 9A. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
TVA's management, including the President and Chief Executive Officer, the Executive Vice President and Chief Financial Officer, and members of the Disclosure Control Committee, including the Vice President and Controller (Principal Accounting Officer), evaluated the effectiveness of TVA's disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) as of September 30, 2019. Based on this evaluation, TVA's management, including the President and Chief Executive Officer, the Executive Vice President and Chief Financial Officer, and members of the Disclosure Control Committee, including the Vice President and Controller (Principal Accounting Officer), concluded that TVA's disclosure controls and procedures were effective as of September 30, 2019, to ensure that information required to be disclosed by TVA in reports that it files or submits under the Exchange Act, is recorded, processed, summarized, and reported, within the time periods specified in the Securities and Exchange Commission's rules and forms, and include controls and procedures designed to ensure that information required to be disclosed by TVA in such reports is accumulated and communicated to TVA's management, including the President and Chief Executive Officer, the Executive Vice President and Chief Financial Officer, and members of the Disclosure Control Committee, including the Vice President and Controller (Principal Accounting Officer), as appropriate, to allow timely decisions regarding required disclosure.
Internal Control over Financial Reporting
(a)Management's Annual Report on Internal Control over Financial Reporting
TVA's management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Exchange Act Rule 13a-15(f) and required by Section 404 of the Sarbanes-Oxley Act. TVA's internal control over financial reporting is designed to provide reasonable, but not absolute, assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with generally accepted accounting principles. Because of the inherent limitations in all control systems, internal control over financial reporting and systems may not prevent or detect misstatements.
TVA's management, including the President and Chief Executive Officer, the Executive Vice President and Chief Financial Officer, and members of the Disclosure Control Committee, including the Vice President and Controller (Principal Accounting Officer), evaluated the design and effectiveness of TVA's internal control over financial reporting as of September 30, 2019, based on the framework in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, TVA's management concluded that TVA's internal control over financial reporting was effective as of September 30, 2019.
Although the effectiveness of internal control over financial reporting was not required to be subject to attestation by TVA's independent registered public accounting firm, TVA has chosen to obtain such a report. Ernst & Young LLP, the independent registered public accounting firm that audited the financial statements included in this Annual Report, has issued an attestation report on TVA's internal control over financial reporting.
(b)Changes in Internal Control over Financial Reporting
During the quarter ended September 30, 2019, there were no changes in TVA's internal control over financial reporting that materially affected, or are reasonably likely to materially affect, TVA's internal control over financial reporting.
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Report of Independent Registered Public Accounting Firm
To the Board of Directors of Tennessee Valley Authority
Opinion on Internal Control over Financial Reporting
We have audited Tennessee Valley Authority’s internal control over financial reporting as of September 30, 2019, based on criteria established in Internal Control- Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO Criteria). In our opinion, Tennessee Valley Authority (the Company) maintained, in all material respects, effective internal control over financial reporting as of September 30, 2019, based on the COSO criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of September 30, 2019 and 2018, the related consolidated statements of operations, comprehensive income (loss), changes in proprietary capital and cash flows for each of the three years in the period ended September 30, 2019, and the related notes and our report dated November 14, 2019 expressed an unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ Ernst & Young LLP
Chattanooga, Tennessee
November 14, 2019
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ITEM 9B. OTHER INFORMATION
On November 14, 2019, the TVA Board approved adjustments to the compensation of Chief Executive Officer Jeffrey J. Lyash for 2020. Mr. Lyash's base salary will increase from $920,000 to $1,058,000. Mr. Lyash was awarded a performance grant ("LTP") of $2,341,000 under TVA's Long-Term Incentive Plan ("LTIP") effective October 1, 2019, which will vest on September 30, 2022. Mr. Lyash was also awarded a retention grant ("LTR") of $1,014,000 under TVA's LTIP effective October 1, 2019, which will vest in three equal increments on September 30, 2020, September 30, 2021, and September 30, 2022.
The two LTIP grants will replace two grants outlined in Mr. Lyash's initial offer letter. The LTP grant of $2,341,000 will replace a grant of $2,024,000, effective October 1, 2019 and vesting September 30, 2022. The LTR grant of $1,014,000 will replace a grant of $876,000, effective October 1, 2019 and vesting fully on September 30, 2022. The LTP grant of $2,024,000 effective October 1, 2019 and vesting September 30, 2021, will remain in place.
On November 14, 2019, Mr. Lyash approved compensation adjustments for the following Named Executive Officers for 2020:

• | The salary for Mr. Thomas will increase from $647,169 to $666,584. Additionally, Mr. Thomas was awarded a LTP grant of $980,000 effective October 1, 2019, which will vest on September 30, 2022. Mr. Thomas also received a LTR grant of $420,000 effective October 1, 2019, which will vest in three equal increments on September 30, 2020, September 30, 2021, and September 30, 2022.

• | The salary for Mr. Skaggs will increase from $620,000 to $663,400. Additionally, Mr. Skaggs was awarded a LTP grant of $990,000 effective October 1, 2019, which will vest on September 30, 2022. Mr. Skaggs also received a LTR grant of $429,000 effective October 1, 2019, which will vest in three equal increments on September 30, 2020, September 30, 2021, and September 30, 2022.

• | The salary for Ms. Quirk will increase from $541,059 to $557,291. Additionally, Ms. Quirk was awarded a LTP grant of $695,000 effective October 1, 2019, which will vest on September 30, 2022. Ms. Quirk also received a LTR grant of $297,000 effective October 1, 2019, which will vest in three equal increments on September 30, 2020, September 30, 2021, and September 30, 2022.

• | The salary for Mr. Rausch will increase from $520,000 to $535,600. Additionally, Mr. Rausch was awarded a LTP grant of $500,000 effective October 1, 2019, which will vest on September 30, 2022. Mr. Rausch also received a LTR grant of $330,000 effective October 1, 2019, which will vest in three equal increments on September 30, 2020, September 30, 2021, and September 30, 2022.

The salary adjustments described above became effective as of October 1, 2019. No adjustments were made to any other existing elements of compensation for these Named Executive Officers for 2020.
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PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE
Directors
The Tennessee Valley Authority Act of 1933 (the "TVA Act") provides that the Tennessee Valley Authority ("TVA") will be administered by a board of nine part-time members appointed by the President of the United States ("U.S.") with the advice and consent of the United States Senate. The Chair of the TVA Board of Directors (the "TVA Board") is selected by the members of the TVA Board. Under the TVA Act, to be eligible to be appointed as a member of the TVA Board, an individual (i) must be a U.S. citizen; (ii) must have management expertise relative to a large for-profit or nonprofit corporate, government, or academic structure; (iii) cannot be a TVA employee; (iv) must make a full disclosure to Congress of any investment or other financial interest that the individual holds in the energy industry; and (v) must affirm support for the objectives and missions of TVA, including being a national leader in technological innovation, low-cost power, and environmental stewardship. In addition, the President of the U.S., in appointing members of the TVA Board, must (i) consider recommendations from other public officials such as the Governors of the states in TVA's service area; individual citizens; business, industrial, labor, electric power distribution, environmental, civic, and service organizations; and the congressional delegations of the states in TVA's service area; and (ii) seek qualified members from among persons who reflect the diversity, including geographical diversity, and needs of TVA's service area. At least seven of the nine TVA Board members must be legal residents of the TVA service area. Currently, TVA has nine active TVA Board members.
TVA Board members serve five-year terms, and at least one member's term ends each year. After a member's term ends, the member is permitted under the TVA Act to remain in office until the earlier of the end of the then-current session of Congress or the date a successor takes office. The TVA Board, among other things, establishes broad goals, objectives, and policies for TVA; develops long-range plans to guide TVA in achieving these goals, objectives, and policies; approves annual budgets; and establishes a compensation plan for employees.
The TVA Board as of November 14, 2019, consisted of the following nine individuals with their ages and terms of office provided:

Directors | Age | Year Current Term Began | Year Term Expires
James R. Thompson, III, Chair(1) | 60 | 2018 | 2021
Kenneth E. Allen | 73 | 2018 | 2021
A.D. Frazier | 75 | 2018 | 2022
Richard C. Howorth | 68 | 2015 | 2020
William B. Kilbride | 68 | 2019 | 2023
Virginia T. Lodge | 69 | 2014 | 2019(2)
John L. Ryder | 70 | 2019 | 2021
Jeff W. Smith | 60 | 2018 | 2022
Ronald A. Walter | 70 | 2014 | 2019(2)

Note
(1) Mr. Thompson assumed the Board Chair role on May 19, 2019.
(2) Although the terms of Director Lodge and Director Walter expired in May 2019, they are permitted under the TVA Act to remain in office until the earlier of the end of the current session of Congress or the date a successor takes office.
Mr. Thompson of Decatur, Alabama, joined the TVA Board in January 2018. Since 2009, he has served as President, Chief Executive Officer ("CEO"), and chair of Corporate Billing, LLC, a commercial finance company. Mr. Thompson previously served as the CEO of First American Bank, Alabama National Bancorporation's largest subsidiary bank, from 1999 until 2008. From 2011 until January 2018, he was also a member of the Board of Directors of Decatur Utilities, one of TVA's local power company customers ("LPCs").
Mr. Allen of White Plains, Kentucky, joined the TVA Board in January 2018. He spent more than 50 years in the coal industry and held a number of executive management positions prior to his retirement in June 2017. Most recently, he served as Executive Vice President and Chief Operating Officer ("COO") of Armstrong Energy, Inc. from July 2014 to June 2017, as Executive Vice President of Operations for Armstrong Energy, Inc. from 2011 to July 2014, and as COO of Armstrong Coal Company, Inc. from December 2013 until June 2017. He is currently a member of the Board of Directors for the First United Bank in Madisonville, Kentucky.
Mr. Frazier of Mineral Bluff, Georgia, joined the TVA Board in January 2018. Since July 2012, he has served as President Emeritus of Georgia Oak Partners, LLC, a private equity company. Mr. Frazier previously held a number of other executive management positions, including chair and Chief Financial Officer ("CFO") of the Chicago Stock Exchange, chair and
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CEO of Danka Business Systems, a reseller of high-end photocopying equipment, president of Caremark, a pharmacy benefit management company, and COO of the Atlanta Committee for the 1996 Olympic Games.
Mr. Howorth of Oxford, Mississippi, joined the TVA Board in July 2011 and began a second term on the TVA Board in December 2015. He is the owner of Square Books, an Oxford independent bookstore he founded in 1979. Mr. Howorth served two terms as the mayor of Oxford, from 2001 to 2009, during which time he was chair of the authority overseeing the Oxford Electric Department. From 2001 to 2009, he also served as a director and officer of the North Mississippi Industrial Development Association, an economic development consortium made up of power association directors and mayors of cities in 29 Mississippi counties in the TVA service area.
Mr. Kilbride of Chattanooga, Tennessee, joined the TVA Board in August 2019. He served as the president and CEO of the Chattanooga Area Chamber of Commerce from July 2014 until his retirement in January 2017, where he led multiple initiatives to attract and retain business to southeast Tennessee. He previously served as the president of the Home Division of Mohawk Industries after earlier holding positions with both Dean Witter Reynolds Financial Services and the New York Stock Exchange.
Ms. Lodge of Nashville, Tennessee, joined the TVA Board in December 2014. She has served as the CEO of FSI Inc., a fulfillment and supply chain company based in Nashville, Tennessee, since March 2012. She served as Commissioner of the Tennessee Department of Human Services from 2003 to 2011. From 2002 to 2003, she worked on Tennessee Governor Phil Bredesen's campaign and transition team. Ms. Lodge was National Director of GoreCorps for the Gore for President Campaign in 2000 and served as Executive Director for Kids Voting of Middle Tennessee from 1994 to 1999.
Mr. Ryder of Memphis, Tennessee, joined the TVA Board in March 2019. He has served as a bankruptcy and election law attorney with Harris Shelton Hanover Walsh, PLLC, since 2000. In addition, he served as General Counsel to the Republican National Committee from 2013 to 2017 and as Chairman of the Republican National Lawyers Association from 2017 to 2018.
Mr. Smith of Knoxville, Tennessee, joined the TVA Board in January 2018. Since April 2000, Mr. Smith has served as the deputy for operations at Oak Ridge National Laboratory ("ORNL"). Since April 2001, he has also served as the President of UT-Battelle Development Corporation, an entity established to develop privately constructed facilities at ORNL. During a six-month special assignment in 2002, he assisted with the creation of the U.S. Department of Homeland Security.
Mr. Walter of Memphis, Tennessee, joined the TVA Board in December 2014. He is currently the President and General Manager of WREG-TV, a Memphis-based television station. Mr. Walter has been employed by WREG-TV since 1987, and assumed his current position in 2004. Mr. Walter was Vice President of Customer Relations for the Memphis Light, Gas and Water Division ("MLGW") from 1982 to 1987. His prior roles at MLGW from 1980 to 1982 included Assistant to the President and Director of Personnel.
Executive Officers
TVA's executive officers as of November 14, 2019, their titles, their ages, and the date their employment with TVA commenced are as follows:

Executive Officers | Title | Age | Employment Commenced
Jeffrey J. Lyash | President and Chief Executive Officer | 58 | 2019(1)
Michael D. Skaggs | Executive Vice President and Chief Operating Officer | 59 | 1994
Sherry A. Quirk | Executive Vice President and General Counsel | 65 | 2015
John M. Thomas, III | Executive Vice President and Chief Financial Officer | 55 | 2005
Van M. Wardlaw | Executive Vice President and Chief External Relations Officer | 59 | 1982
Timothy S. Rausch | Senior Vice President and Chief Nuclear Officer | 55 | 2018(2)
Susan E. Collins | Senior Vice President and Chief Human Resource and Communications Officer | 53 | 2014
Diane T. Wear | Vice President and Controller (Principal Accounting Officer) | 51 | 2008

Note
(1) Mr. Lyash commenced employment with TVA on April 8, 2019.
(2) Mr. Rausch commenced employment with TVA on October 15, 2018.
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Mr. Lyash has served as TVA's President and CEO since April 2019. He previously served as the President and Chief Executive Officer of Ontario Power Generation Inc. (“OPG”), an electric utility, from August 2015 until April 2019. Prior to joining OPG, Mr. Lyash served as the President of the Power Business Unit of Chicago Bridge & Iron Company N.V., an engineering, procurement, and construction company, from July 2013 to August 2015, as Executive Vice President of Energy Supply for Duke Energy Corporation, an electric utility, from July 2012 to December 2012, and as Executive Vice President of Energy Supply for Progress Energy, Inc. (“Progress Energy”), an electric utility, from June 2010 to July 2012. Mr. Lyash joined Progress Energy (formerly Carolina Power & Light Company) in 1993 and held a number of other positions before assuming the role of Executive Vice President of Energy Supply, including Executive Vice President of Corporate Development from July 2009 to June 2010, President and Chief Executive Officer of Progress Energy Florida, Inc., from June 2006 to July 2009, Senior Vice President of Energy Delivery for Progress Energy Florida, Inc., from November 2003 to June 2006, and Vice President of Transmission for Progress Energy Carolinas, Inc., from January 2002 to October 2003. He also held a wide range of management and executive roles in Progress Energy's nuclear program, including Operations Manager, Engineering Manager, Plant Manager, and Director of Site Operations. Mr. Lyash began his career in the utility industry in 1981 and worked for Pennsylvania Power & Light before joining the U.S. Nuclear Regulatory Commission (“NRC”), where he worked from 1984 to 1993. While at the NRC, Mr. Lyash held a number of senior technical and management positions and also worked from June 1984 to May 1985 as an engineer at Browns Ferry Nuclear Plant while on loan to TVA. Mr. Lyash has served as a director for the Electric Power Research Institute (“EPRI”) since 2015 and is currently Chair of the EPRI Board, and he has served as a director for Granite Construction Inc. since June 2018.
Mr. Skaggs was named TVA's Executive Vice President and COO effective October 2018. Since joining TVA in 1994 as Manager of Projects at Watts Bar Nuclear Plant ("Watts Bar"), Mr. Skaggs has held several management positions, including Executive Vice President, Operations from October 2016 to September 2018, Senior Vice President, Watts Bar Operations and Construction from September 2013 to October 2016, Senior Vice President, Nuclear Construction from February 2012 to September 2013, Senior Vice President of Nuclear Generation Development and Construction from October 2011 to February 2012, Site Vice President of Sequoyah Nuclear Plant from November 2010 to October 2011, Vice President of Nuclear Operations Support from December 2009 to November 2010, Site Vice President at Watts Bar from July 2005 to December 2009, and Site Vice President at Browns Ferry Nuclear Plant from July 2004 to July 2005.
Ms. Quirk has served as TVA's Executive Vice President and General Counsel since February 2015. From October 2010 to February 2015, Ms. Quirk was an equity partner in the law firm of Schiff Hardin LLP, which specializes in federal energy regulation, legislation, and power supply transactions. Prior to joining Schiff Hardin, Ms. Quirk was a partner in the Energy Group of Sullivan & Worcester LLP, and a partner in the Energy Group of Verner, Liipfert, Bernhard, McPherson and Hand, specializing in federal energy regulation, legislation, power supply transactions, and state proceedings.
Mr. Thomas has served as TVA's CFO since June 2010 and was also named Executive Vice President in February 2012. He served as Executive Vice President of People and Performance from January 2010 to June 2010, as Senior Vice President, Corporate Governance and Compliance from July 2009 to January 2010, as Controller and Chief Accounting Officer from January 2008 to September 2009, and as the General Manager, Operations Business Services from November 2005 to January 2008. Prior to joining TVA, Mr. Thomas was CFO during 2005 for Benson Security Systems. He was also the Controller of Progress Fuels Corporation from 2003 to 2005 and Controller of Progress Ventures, Inc. from 2001 to 2002, both subsidiaries of Progress Energy.
Mr. Wardlaw was named TVA's Executive Vice President and Chief External Relations Officer in July 2014. Mr. Wardlaw served as Senior Vice President, Customer Relations, from September 2013 to July 2014, as Executive Vice President, Customer Relations, from June 2011 to September 2013, as Executive Vice President, Enterprise Relations, from October 2010 to June 2011, as Acting Executive Vice President of Strategy and Planning from January 2010 until September 2010, as Executive Vice President of Power Supply and Fuels from July 2008 to August 2010, as Senior Vice President, Commercial Operations and Fuels from January 2007 to June 2008, as Vice President, Bulk Power Trading from September 2006 to December 2006, and as Vice President of Transmission and Reliability from December 2000 to September 2006. Mr. Wardlaw began his career with TVA in January 1982 as an electrical engineer, and has also worked in customer service, marketing, and field services.
Mr. Rausch joined TVA in October 2018 as Senior Vice President and Chief Nuclear Officer. Before joining TVA, Mr. Rausch served as the Senior Vice President and Chief Nuclear Officer of Talen Energy Corporation from June 2015 until September 2018 and as the Senior Vice President and Chief Nuclear Officer of PPL Generation, LLC from July 2009 to June 2015. Mr. Rausch has 25 years of experience in virtually all the disciplines of the nuclear power industry, including roles as Site Vice President, Plant General Manager, and Director of Engineering.
Ms. Collins joined TVA in May 2014 as Vice President of Human Resources, and she was named Senior Vice President and Chief Human Resources Officer in February 2016. Before joining TVA, Ms. Collins served as Senior Vice President of Human Resources for Constellation Energy Nuclear Group, LLC from 2009 to 2014 and as Vice President of Human Resources for Constellation Energy from 2008 to 2009. In June 2019, she was named Senior Vice President, Chief Human Resources and Communications Officer.
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Ms. Wear has served as TVA's Vice President and Controller since March 2012. Ms. Wear was the Assistant Controller from February 2010 to March 2012. Between April 2008, when she joined TVA, and February 2010, Ms. Wear was the General Manager, External Reporting/Accounting Policy and Research. Prior to joining TVA, Ms. Wear was a Managing Director at PricewaterhouseCoopers LLP. Ms. Wear joined a predecessor firm to PricewaterhouseCoopers LLP in January 1992.
Disclosure and Financial Code of Ethics
TVA has a Disclosure and Financial Ethics Code ("Financial Ethics Code") that applies to all executive officers (including the CEO, CFO, and Controller) and directors of TVA as well as to all employees who certify information contained in quarterly reports or annual reports or who have responsibility for internal control self-assessments. The Financial Ethics Code includes provisions covering conflicts of interest, ethical conduct, compliance with applicable laws, rules, and regulations, responsibility for full, fair, accurate, timely, and understandable disclosures, and accountability for adherence to the Financial Ethics Code. TVA will provide a current copy of the Financial Ethics Code to any person, without charge, upon request. Requests may be made by calling 888-882-4975 or by sending an e-mail to: investor@tva.com. Any waivers of or changes to provisions of the Financial Ethics Code that require disclosure pursuant to applicable Securities and Exchange Commission requirements will be promptly disclosed to the public, subject to limitations imposed by law, on TVA's website at: www.tva.gov. Information contained on TVA's website shall not be deemed to be incorporated into, or to be a part of, this Annual Report.
Committees of the TVA Board
The TVA Board has an Audit, Risk, and Regulation Committee established in accordance with the TVA Act. TVA's Audit, Risk, and Regulation Committee consists of James R. Thompson, III, Kenneth E. Allen, John Ryder, and Virginia T. Lodge. Director Thompson is an "audit committee financial expert" as defined in Item 407(d)(5) of Regulation S-K under the Securities Exchange Act of 1934 (the "Exchange Act").
TVA is exempted by Section 37 of the Exchange Act from complying with Section 10A(m)(3) of the Exchange Act, which requires each member of a listed issuer's audit committee to be an independent member of the board of directors of the issuer. The TVA Act contains certain provisions that are similar to the considerations for independence under Section 10A(m)(3) of the Exchange Act, including that to be eligible for appointment to the TVA Board, an individual shall not be an employee of TVA and shall make full disclosure to Congress of any investment or other financial interest that the individual holds in the energy industry.
Under Section 10A(m)(2) of the Exchange Act, which applies to TVA, the audit committee is directly responsible for the appointment, compensation, and oversight of the external auditor; however, the TVA Act assigns the responsibility for engaging the services of the external auditor to the TVA Board.
The TVA Board has also established the following committees in addition to the Audit, Risk, and Regulation Committee:

• | Finance, Rates, and Portfolio Committee,

• | External Relations Committee,

• | People and Performance Committee, and

• | Nuclear Oversight Committee.

ITEM 11. EXECUTIVE COMPENSATION
Compensation Discussion and Analysis
The Compensation Discussion and Analysis ("CD&A") focuses on the compensation of TVA's CEO, retired CEO, CFO, and three other most highly compensated executive officers serving at the end of fiscal year 2019. Collectively, these officers are TVA's 2019 Named Executive Officers ("NEOs"):
•Jeffrey J. Lyash, President and CEO;
•William D. Johnson, Retired President and CEO;
•John M. Thomas, III, Executive Vice President and Chief Financial Officer;
•Michael D. Skaggs, Executive Vice President and Chief Operating Officer;
•Sherry A. Quirk, Executive Vice President and General Counsel; and
•Timothy S. Rausch, Senior Vice President and Chief Nuclear Officer.
On November 14, 2018, Mr. Johnson gave notice to the Board of his intent to retire. The Board conducted a search for a new CEO, and Mr. Lyash was hired effective April 8, 2019. Mr. Johnson assisted with the CEO transition and retired effective May 2, 2019.
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Executive Summary
TVA is a corporate agency and instrumentality of the U.S. that was created in 1933 by federal legislation in response to a request 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 to a population of nearly 10 million people.
2019 Compensation Highlights
2019 At-Risk Compensation. Based on its annual performance and productivity, TVA rewards employees through its Winning Performance Team Incentive Plan ("WPTIP") and Executive Annual Incentive Plan ("EAIP"). In addition, certain executives in critical positions, including the NEOs, participate in the Long-Term Incentive Plan ("LTIP"). The LTIP provides for long-term performance ("LTP") grants and long-term retention ("LTR") grants. Similar to incentive programs at other utilities, awards under the WPTIP, EAIP, and the performance-based component of the LTIP are not part of base pay but are "at risk" and require employees to reach or exceed specific performance targets in order for payments to be earned.
For 2019, the scorecard results for the EAIP were 116 percent of the target opportunity. The following factors contributed to overall performance:

• | Achieved better than top decile safety performance (recordable incident rate);

• | Achieved lowest level of debt in nearly 30 years;

• | Maintained strong transmission reliability performance; and

• | Helped to attract and retain approximately 66,500 jobs and over $8.9 billion in capital investment to the TVA service area.

In addition, for the three-year period ending September 30, 2019, the TVA Board-approved LTP awards to NEOs under the LTIP were 116 percent of the target opportunity primarily because of overall strong performance and financial discipline. Throughout the 2017 - 2019 performance period, TVA accomplished the following objectives:

• | Strong financial performance reduced debt to the lowest level in almost 30 years and met the 10-year Long-Range Financial Plan goals in six years,

• | Strong transmission system reliability performances, and

• | Outstanding customer survey results.

2019 Compensation Adjustments. On November 14, 2018, the TVA Board approved the compensation of CEO William Johnson for 2019. On October 1, 2018, Mr. Johnson's salary increased from $1,050,000 to $1,150,000. He was awarded a LTP grant of $2,537,500 under the LTIP which would have fully vested on September 30, 2021. He was also awarded a LTR grant under the LTIP of $1,087,500, which provided for vesting in three equal increments on September 30, 2019, 2020, and 2021. Based on the provisions of the LTIP, Mr. Johnson will receive prorated portions of all outstanding LTIP grants based on the date of his retirement of May 2, 2019.
On November 14, 2018, Mr. Johnson approved compensation adjustments and grants for the following NEOs for 2019:

• | The salary for Mr. Thomas increased from $628,319 to $647,169. Additionally, Mr. Thomas was awarded a LTP grant of $880,000 effective October 1, 2018, which will fully vest on September 30, 2021. Mr. Thomas also received a LTR grant of $380,000 effective October 1, 2018, which will vest in three equal increments on September 30, 2019, 2020, and 2021.

• | The salary for Mr. Skaggs increased from $520,000 to $620,000. Additionally, Mr. Skaggs was awarded a LTP grant of $980,000 effective October 1, 2018, which will fully vest on September 30, 2021. Mr. Skaggs also received a LTR grant of $420,000 effective October 1, 2018, which will vest in three equal increments on September 30, 2019, 2020, and 2021.

• | The salary for Ms. Quirk increased from $510,000 to $541,059. Additionally, Ms. Quirk was awarded a LTP grant of $685,000 effective October 1, 2018, which will fully vest on September 30, 2021. Ms. Quirk also received a LTR grant of $290,000 effective October 1, 2018, which will vest in three equal increments on September 30, 2019, 2020, and 2021.

Mr. Rausch commenced employment at TVA effective October 15, 2018, at a base salary of $520,000. Additionally, Mr. Rausch was awarded a LTP grant of $404,250 effective October 1, 2018, which will fully vest on September 30, 2021. Mr. Rausch also received a LTR grant of $173,250 effective October 1, 2018, which will vest in three equal increments on September 30, 2019, 2020, and 2021.
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On April 8, 2019, Mr. Lyash commenced employment as TVA’s President and Chief Executive Officer and his offer letter outlines the following compensation components:

• | Annual Salary of $920,000

• | EAIP target annual incentive opportunity of 150% of his annual salary. He was eligible for an EAIP award for fiscal year 2019, and the amount of the award was prorated based on the number of months he was employed during the fiscal year and was based on individual and corporate performance.

• | LTP target grant opportunity of 220% of his annual salary.

▪ | Effective October 1, 2019, LTP grant of $2,024,000 for the three-year performance cycle ending September 30, 2021. This grant fully vests at the end of the performance cycle.

▪ | Effective October 1, 2019, LTP grant of $2,024,000 for the three-year performance cycle ending September 30, 2022. This grant fully vests at the end of the performance cycle.

• | LTR target grant opportunity of 95.2% of his annual salary.

▪ | Effective October 1, 2019, LTR grant of $876,000 for the three-year performance cycle ending September 30, 2022. This grant vests in one-third increments annually on the applicable vesting dates: $292,000 on September 30, 2020, $292,000 on September 30, 2021, and $292,000 on September 30, 2022.

• | Recruitment and relocation incentive of $1,784,000 which will vest and pay in three installments as long as Mr. Lyash remains employed by TVA on the applicable vesting dates: $400,000 on September 30, 2019, $1,092,000 on September 30, 2020, and $292,000 on September 30, 2021.

• | Sign-On Bonus of $380,000 which remains subject to certain repayment conditions.

Amendment of Compensation Plan. On August 22, 2019, the Board approved an amended and restated compensation plan for employees ("Compensation Plan"). The changes to the plan were editorial in nature. Among other things, the changes strengthened the description of TVA’s compensation components and updated language related to qualified and non-qualified retirement plans.
Philosophy
TVA is committed to achieving its mission to serve the people of the Tennessee Valley to make life better. It does this through a focus on three core areas: Energy, Environment, and Economic Development. The compensation structure of TVA is developed to reinforce TVA's mission and strategic imperatives.
TVA aims to achieve its mission by attracting, retaining, and motivating highly qualified and committed executives to guide the organization's strategy and performance. TVA follows a Compensation Plan as adopted by the TVA Board in accordance with the guidance of the TVA Act. The Compensation Plan is designed to:
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• | Provide market-based, competitive compensation levels so TVA can attract, retain, and motivate highly competent employees. Target total direct compensation generally is determined by reference to the 50th percentile of the relevant labor market, although some positions are determined by reference to up to the 75th percentile based on labor market scarcity and other issues.

• | Reward employees for performance. A substantial portion of executive pay, including pay for the NEOs, is tied to performance improvement. As illustrated in the charts below, at least half of each NEO's target total direct compensation opportunity is delivered through performance-based incentive programs.

• | Align the organization's short-term and long-term goals and objectives with compensation opportunities by providing a mix of salary and performance-based short-term and long-term incentives.

• | Align performance and productivity improvement at all levels by setting consistent performance goals and objectives for all levels of the organization.

The TVA Board follows these requirements of the TVA Act in designing and implementing its Compensation Plan:

• | Compensation will be based on an annual survey of benchmark compensation for similar positions in private industry, including engineering and electric utility companies, publicly-owned electric utilities, and federal, state, and local governments; and

• | Compensation will take into account education, experience, level of responsibility, geographic differences, and retention and recruitment needs.

Authority for the Executive Compensation Program
The TVA Board, under the authority of the TVA Act, has responsibility for establishing compensation for TVA employees, including the NEOs. The TVA Board is directed under Section 2 of the TVA Act to establish a plan that specifies all compensation (such as salary and any other pay, benefits, incentives, or other form of remuneration) for the CEO and TVA employees.
The TVA Act also provides that:

• | The TVA Board will annually approve all compensation (such as salary and any other pay, benefits, incentives, or other form of remuneration) for all managers and technical personnel who report directly to the CEO (including any adjustment(s) to compensation);

• | On the recommendation of the CEO, the TVA Board will approve the salaries of employees whose salaries would be in excess of Level IV of the Executive Schedule of the U.S. Government ($166,500 in 2019); and

• | The CEO will determine the salary and benefits of employees whose annual salary is not greater than Level IV of the Executive Schedule ($166,500 in 2019).

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Under the authority of the TVA Act, the TVA Board, its People and Performance Committee (the "Committee"), and individual TVA Board members are involved in compensation matters. The TVA Board has delegated to the CEO the authority to approve, or delegate to others the authority to approve, all personnel and compensation actions for which the TVA Board is responsible but has not reserved for itself. In addition, the TVA Board has taken the following actions to delegate authority with respect to executive compensation:

• | The TVA Board has delegated to the TVA Board Chair, in consultation with the Committee and with input from individual members of the TVA Board, the authority to evaluate and rate the CEO's performance during the year, and the authority to approve any payout to the CEO under the EAIP, based on, among other things, the CEO's evaluated performance during the year.

• | The TVA Board has authorized the CEO to set or adjust compensation for present or future direct reports within compensation ranges of 80 percent to 110 percent of the target total direct compensation for comparable positions, as well as to approve the parameters under which such executives may participate in certain supplemental benefit plans such as TVA's Supplemental Executive Retirement Plan ("SERP"), provided that the CEO may not finally set or adjust such compensation until the TVA Board members have been notified of the proposed compensation and given the opportunity to ask the Committee, or the full TVA Board, to review the proposed compensation before it becomes effective.

• | The TVA Board has delegated to the CEO, in consultation with the Committee and with input from individual members of the TVA Board, the authority to approve the individual performance goals for the CEO's direct reports and the authority to evaluate and rate the performance of the CEO's direct reports during the year against such performance goals.

TVA Board Committee Oversight
The Committee was responsible for oversight of executive compensation pursuant to the Compensation Plan, review of this Compensation Discussion and Analysis, and review of performance goal achievement for 2019. As delegated by the TVA Board, the Committee also (1) reviewed proposed CEO actions to set or adjust compensation for his direct reports, (2) consulted with the TVA Board Chair about the Chair's proposed evaluation and rating of the CEO's performance during the year and about the proposed payout to the CEO under the EAIP, and (3) consulted with the CEO on the proposed individual performance goals and evaluation and performance ratings for the CEO's direct reports for the year. The Committee used the independent consulting firm Frederic W. Cook & Co., Inc. ("FW Cook") in 2019 to help evaluate competitive compensation. The Committee assessed certain independence factors and determined the firm's work raised no potential conflict of interest.
Assessment of Risk
TVA's Enterprise Risk Management Organization, in coordination with other members of TVA's management, including Human Resources and Total Rewards, conducts an annual assessment of enterprise level risks which includes considering risks arising from TVA's compensation policies and practices, in order to identify any risks that are reasonably likely to have a material adverse effect on the organization and its achievement of its strategic goals and objectives.
Based on the results of this assessment, no risks were identified with the compensation policies and practices that are reasonably likely to have a material adverse effect on TVA's achievement of its strategic goals and objectives.
Use of Market Data and Benchmarking
TVA generally determines target total direct compensation for executives based on the relevant labor market. After compiling market compensation for the positions at the beginning of 2019, the Committee, with assistance from FW Cook, used the information to:

• | Assess target compensation level and incentive opportunity competitiveness; and

• | Determine appropriate target compensation levels and incentive opportunities to maintain the desired degree of market competitiveness.

The relevant labor market for most of TVA's executives, including the NEOs, consisted of both private and publicly-owned companies in the energy services industry of similar revenue and scope to TVA. TVA's peer group is reviewed on an annual basis. For the survey-based analysis, TVA referenced a sample from the 2018 Willis Towers Watson Energy Services Executive Compensation Database consisting of (i) 28 investor-owned utilities with revenues greater than or equal to $3 billion plus (ii) five additional government entities. Data from this sample were further regressed to TVA's size based on revenue. For NEO roles, the survey analysis was supplemented with public compensation data from a separate proxy peer group of investor-owned utilities. TVA approximated the median of this proxy group in terms of revenue. For executives with both proxy and survey benchmarks, competitive comparisons were made relative to a "market composite" or an average of the survey and proxy data.
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The following chart outlines the companies that constituted the survey sample and proxy peer group used to benchmark NEO compensation for 2019:

Company | Investor Owned Utilities with Revenue Greater than or Equal to $3 Billion Which Participated in 2018 Willis Towers Watson Energy Services Survey | Government Entities Which Participated in 2018 Willis Towers Watson Energy Services Survey | Proxy Peer Group of Investor Owned Utilities
AES Corp. | þ |  | þ
Alliant Energy | þ |  |
Ameren | þ |  | þ
American Electric Power Co., Inc. | þ |  | þ
Calpine Corp. | þ |  | þ
CenterPoint Energy, Inc. | þ |  | þ
CMS Energy Corp. | þ |  | þ
Consolidated Edison |  |  | þ
Dominion Energy | þ |  | þ
DTE Energy Co. |  |  | þ
Duke Energy Corp. | þ |  | þ
Edison International | þ |  | þ
Energy Northwest |  | þ |
Entergy Corp. | þ |  | þ
Eversource Energy | þ |  | þ
Exelon Corp. | þ |  | þ
FirstEnergy Corp. | þ |  | þ
JEA |  | þ |
New York Power Authority |  | þ |
NextEra Energy, Inc. | þ |  | þ
NiSource | þ |  | þ
NRG Energy | þ |  | þ
Omaha Public Power |  | þ |
Pacific Gas and Electric Co. | þ |  | þ
Pinnacle West Capital | þ |  |
PPL Corp. | þ |  | þ
Public Service Enterprise Group Inc. | þ |  | þ
Salt River Project |  | þ |
SCANA | þ |  |
Sempra Energy | þ |  | þ
Southern Company | þ |  | þ
UNS Energy | þ |  |
Vistra Energy | þ |  |
WEC Energy | þ |  |
Xcel Energy | þ |  | þ

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Executive Compensation Program Components
The primary compensation program components for 2019 for the NEOs are summarized in the diagram below and are briefly described in the table and the narrative that follow the diagram.

Primary Compensation Program Components for Named Executive Officers in 2019
Compensation Component |  | Objective |  | Key Features
Annual Salary |  | Provides fixed base level of compensation to executives to encourage hiring and retention of qualified individuals |  | - Annual salary is determined by reference to median (50th percentile) for similar positions at other companies in TVA's peer group or above the median (50th to 75th percentile) for positions affected by market scarcity, recruitment and retention issues, and other business reasons. - Typically reviewed annually to consider changes in benchmark salaries and/or exceptional individual merit performances.
EAIP |  | Incentivizes performance by providing at-risk compensation tied to attainment of pre-established performance goals for the fiscal year |  | - Annual incentive payouts are based on the results of established goals of an enterprise scorecard, as determined from year to year by the TVA Board or the CEO, as applicable. Annual incentive payouts may be impacted by a corporate multiplier or adjusted by the TVA Board or CEO, as applicable, based on the evaluation of performance during the year. - Target annual incentive opportunities increase with position and responsibility and are based in part on the opportunities other companies in TVA's peer group provide to those in similar positions. - Typically reviewed annually to consider changes in benchmark annual incentives.
LTIP |  | Incentivizes performance and retention by providing performance-based and retention-based grants that are tied to a vesting schedule |  | - Participation is limited to key positions that have the ability to significantly impact the long-term financial and/or operational objectives critical to TVA's overall success. - LTP awards are granted annually with a three-year vesting cycle. Awards are variable at-risk opportunities based on achieved level of performance (i.e., scorecard results for the three-year performance period). - LTR awards may be granted annually and will vest and pay out in three equal increments annually over three years, subject to the participant being employed through such dates, but are payable upon death or disability if earlier on a pro-rated basis.
Retirement Plans (Qualified Plans and SERP) |  | Provides compensation beginning with retirement or termination of employment (if vesting requirements are satisfied) with enhanced compensation for certain executives to provide an additional incentive for hiring and retention of qualified individuals |  | - Broad-based plans available to full-time employees of TVA that are qualified under Internal Revenue Service ("IRS") rules and are similar to the qualified plans provided by other companies in TVA's peer group. - Certain executives in critical positions also participate in a non-qualified pension plan that provides supplemental pension benefits at compensation levels that are higher than the limits specified by IRS regulations for qualified pension plans. These supplemental benefits are comparable to those provided by other companies in TVA's peer group.

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Salary. Annual salary is determined by reference to the median (50th percentile) for similar positions at other companies in TVA's peer group or above the median (50th to 75th percentile) for positions affected by market scarcity, recruitment and retention issues, and other business reasons. In general, salary is reviewed annually with increases awarded based on prior year performance, the executive's role and responsibilities, and to bring salaries into alignment with the market.
The salaries of the NEOs for 2019 and 2018 were as follows:

Executive | 2019(1) | 2018 | Percent Change
Mr. Lyash | $ | 920,000 |  | N/A |  | N/A |
Mr. Johnson | 1,150,000 |  | $ | 1,050,000 |  | 9.5 | %
Mr. Thomas | 647,169 |  | 628,319 |  | 3.0 | %
Mr. Skaggs(2) | 620,000 |  | 520,000 |  | 19.2 | %
Ms. Quirk | 541,059 |  | 510,000 |  | 6.1 | %
Mr. Rausch | 520,000 |  | N/A |  | N/A |

Note
(1) All 2019 salary changes were effective on October 1, 2018. Mr. Lyash commenced employment with TVA on April 8, 2019 and Mr. Rausch commenced employment with TVA on October 15, 2019.
(2) Mr. Skaggs was named TVA's Executive Vice President and COO effective October 2018 and received a promotional compensation adjustment.
Annual Incentive Compensation. All executives, including the NEOs, participate in the EAIP. The EAIP is designed to encourage and reward executives for successfully achieving annual financial and operational goals. For 2019, an executive's annual incentive payment under the EAIP was calculated as follows:

EAIP Amount | = | Annual Salary | X | Annual Target Incentive Opportunity | X | Percent of Opportunity Achieved (0% to 150%) | X | Corporate Multiplier (0 to 1.00) | X | Individual Performance Multiplier (0% to 125%)

Each component of this calculation is discussed below (except for annual salary, which is discussed above).
Annual Target Incentive Opportunity. Annual incentive opportunities for participants in the EAIP generally increase with position and responsibility. For 2019, Mr. Lyash's and Mr. Johnson's target EAIP award opportunities were approved at 150 percent of salary. In October 2018, Mr. Johnson evaluated the appropriateness of the EAIP award opportunities for the other NEOs and made no changes. Accordingly, target EAIP award opportunities of the NEOs for 2019 were as follows:

Named Executive Officers | 2019 Target Annual Incentive Opportunity(1)
Mr. Lyash | 150%
Mr. Johnson | 150%
Mr. Thomas | 80%
Mr. Skaggs | 80%
Ms. Quirk | 70%
Mr. Rausch | 70%

Note
(1) Represents a percent of each NEO's salary.
Percent of Opportunity Achieved. TVA had one organizational scorecard for the 2019 EAIP (TVA Enterprise Scorecard). This scorecard was also used to determine annual incentive payouts for all non-executive TVA employees who participated in TVA's 2019 WPTIP.
Once scorecard results were calculated, the CEO, after consulting with the TVA Board, approved the scorecard result at 116 percent. The Chair of the TVA Board, in consultation with the Committee and with input from the individual members of the TVA Board, then recommended and approved a payout of 116 percent for the CEO and the retired CEO.
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The goals and associated weightings for the scorecard and the adjusted results achieved follow:

TVA 2019 Enterprise Scorecard
Enterprise Measures | Weight | Threshold | Target | Stretch | Actual
TVA Total Spending ($ Million)(1) | 40% | $ | 4,862 |  | $ | 4,725 |  | $ | 4,589 |  | $ | 4,467 |
Load Not Served(2) | 30% | 4.8 |  | 4.0 |  | 3.6 |  | 3.7 |
Nuclear Unit Capability Factor ("UCF") (%)(3) | 15% | 89.5 | % | 90.3 | % | 91.1 | % | 89.8 | %
Combined Cycle Seasonal Equivalent Forced Outage Rate ("EFOR") (%)(4) | 10% | 3.3 | % | 2.0 | % | 1.5 | % | 7.5 | %
Coal Seasonal Equivalent Forced Outage Rate (%)(5) | 5% | 13.6 | % | 12.1 | % | 10.8 | % | 12.7 | %
Scorecard Result |  | 116%

Notes
(1) TVA Total Spending means total non-fuel O&M + total capital expenses for corporate and operational strategic business unit organizations (excludes Board of Directors).
(2) Load Not Served ("LNS") is a measure of the magnitude and duration of transmission system outages that affect TVA customers and is expressed in system minutes. LNS events caused by TVA on a distributor system will also count as a TVA event even if the TVA system remains energized. LNS excludes interruptions due to declared major events.
(3) UCF is the ratio of available energy generation, which excludes events outside of management control, over a given period of time to the reference energy generation over the same time period.
(4) Combined Cycle Seasonal EFOR measures the generation lost due to forced events as a percentage of time the unit would have been scheduled to run. This measure runs from December to March and June to September for 2019. Based on Generating Availability Data System ("GADS") event reporting guidelines for megawatt hour losses. Excludes GADS events classified as "Outside Management Control." Targets exclude any newly commissioned units for first full fiscal year of operations.
(5) Coal Seasonal EFOR measures the generation lost due to forced events as a percentage of time the unit would have been scheduled to run. This measure runs from December through March and June through September and includes all coal plants. Based on GADS event reporting guidelines for megawatt hour losses. Excludes GADS events classified as "Outside Management Control." Targets exclude any forecasted units to be retired in fiscal year of retirement.
Corporate Multiplier. The TVA Board approved the use of a corporate multiplier for the WPTIP and EAIP. The corporate multiplier ranges between 0 and 1.0 and can be used only for purposes of reducing the amount of the award. For 2019, the TVA Board determined that the corporate multiplier should be 1.0 based on the following:

• | Safety better than top decile;

• | Strong financial performance reduced debt to the lowest level in almost 30 years and met the 10-year Long-Range Financial Plan goals in six years;

• | Zero Board level significant events; and

• | Strong role in stimulating economic development and investment.

Corporate Multiplier | Plan | Actual
Safety - Recordable Incident Rate (RIR)(1) | 0.00 |  | 0.44 |
Financial Health |  |
Total Financing Obligations (TFO) and Liabilities ($ Billion)(2) | $ | 23.8 |  | $ | 22.5 |
Operating Cash Flow ($ Million)(3) | $ | 3,146 |  | $ | 3,720 |
Net Income ($ Million)(4) | $ | 1,363 |  | $ | 1,417 |
Jobs Created and Retained(5) | 50,000-75,000 |  | 66,572 |
Board Level Significant Events(6) | 0 |  | 0 |

Notes
(1) Recordable Incident Rate is defined as the number of recordable injuries (as defined by TVA's safety program) per 200,000 employee-hours worked by TVA employees and staff augmentation contractors (excluding hearing events).
(2) Total Financing Obligations and Liabilities is calculated by subtracting contributions to unfunded liabilities from the sum of (1) long-term debt, net (including unamortized premiums/discounts), (2) short-term debt, net, (3) leaseback obligations, (4) energy prepayment obligations, and (5) variable interest entities ("VIE").
(3) Operating Cash Flow is the amount of cash generated from power production and other mission-related activities. It is generally defined as operating revenues received less cash payments made for operating expenses. See Item 8, Financial Statements and Supplementary Data — Consolidated Statements of Cash Flows for additional information.
(4) Net Income consists of the organization's net earnings derived by adjusting revenues for the cost of doing business, including the cost of sales, depreciation, interest, taxes, and other expenses. See Item 8, Financial Statements and Supplementary Data - Consolidated Statements of Operations for additional information.
(5) Jobs Created and Retained measures the number of new or retained jobs in the Tennessee Valley for which TVA has played a role in the recruitment or retention of the economic development project.
(6) Board Level Significant Events include items deemed materially significant to the TVA Board and that affect TVA's reputation with its customers and its stakeholders, the organizational health of the workforce, or TVA's impact on the public at large.
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Individual Performance Multiplier. Annually, individual goals are established at the beginning of each performance cycle. Once all other preliminary 2019 EAIP payouts were calculated and the corporate multiplier was applied, Mr. Lyash, as CEO, and in consultation with the Committee, evaluated each NEO's performance based upon individual performance goals (except his own) to determine the individual performance multiplier used to calculate his or her payout as set forth in the formula above. Each of the non-CEO NEOs was assigned an Individual Performance Multiplier of 100 percent except for Mr. Thomas, who was assigned an Individual Performance Multiplier of 110 percent based on his strong performance during the fiscal year.
In addition, the TVA Board Chair, in consultation with the Committee and with input from individual members of the TVA Board, evaluated Mr. Lyash's performance as CEO during 2019 to determine his Individual Performance Multiplier under the EAIP. Based on this review, the TVA Board Chair decided that Mr. Lyash's final Individual Performance Multiplier should be 112 percent based on TVA's 2019 performance. This recommendation was based on TVA’s strong financial performance including the development of a 10-year financial plan, focus on people performance excellence and developing the workforce for sustained optimal performance, engagement of key stakeholders, recognition of embracing continuous improvement, and successful demonstration of TVA values and behaviors.
EAIP Payouts. As a result of the above process, the NEOs were awarded the following EAIP payouts for 2019 in comparison to the 2019 target payouts:

2019 EAIP Payouts
Named Executive Officers |  | Salary |  | Target EAIP Incentive Opportunity (% of Salary) |  | Target EAIP Payout |  | Scorecard Results After Application of Corporate Multiplier |  | Individual Performance Multiplier |  | Actual EAIP Payment
Jeffrey J. Lyash(1) |  | $ | 920,000 |  |  | 150% |  | $ | 663,462 |  |  | 116% |  | 112% |  | $ | 861,969 |
William D. Johnson(2) |  | 1,150,000 |  |  | 150% |  | 1,009,409 |  |  | 116% |  | 100% |  | 1,170,915 |
John M. Thomas, III |  | 647,169 |  |  | 80% |  | 517,735 |  |  | 116% |  | 110% |  | 660,630 |
Michael D. Skaggs |  | 620,000 |  |  | 80% |  | 496,000 |  |  | 116% |  | 100% |  | 575,360 |
Sherry A. Quirk |  | 541,059 |  |  | 70% |  | 378,741 |  |  | 116% |  | 100% |  | 439,340 |
Timothy Rausch(3) |  | 520,000 |  |  | 70% |  | 350,000 |  |  | 116% |  | 100% |  | 406,000 |

Note
(1) Mr. Lyash's Target EAIP Payout was prorated based on time in position, April 8, 2019 through September 30, 2019. Target for a full performance period would be $1,380,000.
(2) Mr. Johnson's Target EAIP Payout was prorated based on retirement and time in position, October 1, 2018 through May 1, 2019. Target for a full performance period would be $1,725,000.
(3) Mr. Rausch's Target EAIP Payout was prorated based on time in position, October 15, 2018 through September 30, 2019. Target for a full performance period would be $364,000.
Awards to the NEOs under the EAIP for 2019 are reported in the "Non-Equity Incentive Plan Compensation" column in the Summary Compensation Table.
Long-Term Incentive Compensation. In addition to the EAIP, certain executives in critical positions, including the Named Executive Officers, participate in the company's long-term compensation plans. These individuals make decisions that significantly influence the development and execution of TVA's long-term strategic objectives. As such, the long-term compensation plans are designed to reward executives for helping TVA improve in areas directly related to TVA's long-term success by:

• | Using enterprise-wide performance criteria that are directly aligned with TVA's mission;

• | Using a "cumulative" performance approach to measure performance achieved over a three-year period with a new three-year performance cycle beginning each year;

• | Using a potential payment range of 50 percent to 150 percent of target incentive opportunity to enable awards that are commensurate with performance achievements; and

• | Establishing award opportunities for each performance cycle at levels that approximate median levels of competitiveness with TVA's peer group and adhering to the Committee's policy that (i) approximately 70 to 80 percent of each executive's total long-term incentive opportunity be performance-based (under the performance-based awards under the LTIP) and (ii) approximately 20 to 30 percent of each executive's total long-term incentive opportunity be retention-oriented under the LTIP as described below under Long-Term Retention Arrangements.

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Effective October 1, 2018, TVA granted the following LTP awards:

Named Executive Officers | LTP/Long-Term Performance Grant(1)
Mr. Lyash(2) |  | N/A |
Mr. Johnson(3) |  | $ | 2,537,500 |
Mr. Thomas |  | 880,000 |
Mr. Skaggs |  | 980,000 |
Ms. Quirk |  | 685,000 |
Mr. Rausch |  | 404,250 |

Note
(1) All awards vest September 30, 2021, and the actual amount the executives receive upon payout may vary based on organizational performance under the LTIP.
(2) Mr. Lyash did not receive a LTP grant because he was not employed on the date the grants were issued, October 1, 2018. He was eligible for a grant on October 1, 2019.
(3) Mr. Johnson's LTP was adjusted to $493,403 upon retirement, which represents the prorated portion of the grant based on the number of months he was employed during the performance cycle.
For the three-year cycle ended September 30, 2019, the TVA Board approved three overall long-term incentive measures of TVA performance to be applied to all participants in the LTIP:

• | Non-Fuel Delivered Cost of Power;

• | Load Not Served (the product of the percentage of total load-not-served multiplied by the number of minutes in the measurement period); and

• | External Measures (including external nuclear performance indicators, stakeholder survey, media tone, customer survey, and Board level significant events).

The Non-Fuel Delivered Cost of Power performance measure is a financial measure not affected by weather or customer behavior. The Non-Fuel Delivered Cost of Power measure is equal to the sum of (i) non-fuel operating and maintenance expense, (ii) base capital expense, (iii) interest expense, and (iv) other expense divided by budgeted electric power sales. TVA chooses to use this measure as it drives performance through activities that management can control. The 2017-2019 performance cycle had a threshold goal of 3.65, a target goal of 3.51, and a stretch goal of 3.37.
The Load Not Served performance measure reflects the percentage of total load not served multiplied by the number of minutes in the period (with the value expressed in system minutes and excluding events during declared major storms) during the three-year cycle ended September 30, 2019, with a threshold goal of 4.8, a target goal of 4.0, and a stretch goal of 3.5. Load Not Served events caused by TVA on a distributor system will also count as a TVA event even if TVA's system remains energized.
The External Measures represent TVA's performance in areas including external nuclear performance indicators, stakeholder survey, media tone, customer loyalty, and Board level significant events. Targets for the External Measures are based on making incremental improvements in external perceptions of TVA's performance and brand. The nuclear performance measure was based on 2019 results, with a threshold goal of 88.0 (third quartile), a target goal of 91.0 (between median and top quartile), and a stretch goal of 94.0 (better than top quartile). The media tone, stakeholder survey, customer survey, and Board level significant events measures were calculated using an average of the 2017, 2018, and 2019 results. The media tone measure had a threshold goal of 85.0, a target goal of 89.0, and a stretch goal of 91.7. The stakeholder survey measure had a threshold goal of 81.0, a target goal of 82.5, and a stretch goal of 84.0. The customer survey measure had a threshold goal of 64.7, a target goal of 66.3, and a stretch goal of 68.0. The TVA Board level significant events measure had a threshold goal of two unfavorable events, a target goal of zero events, and a stretch goal of two favorable events.
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The following table shows the performance goals and weighting and percent of opportunity achieved for the performance-based awards (LTP) under the LTIP for the three-year cycle ended September 30, 2019:

TVA 2017 - 2019 Long-Term Incentive Plan Scorecard
Long-Term Incentive Measure | Weight | Threshold | Target | Stretch | Actual
Non-Fuel Delivered Cost of Power (2017-2019) | 40% | 3.65 | 3.51 | 3.37 | 3.46
Load Not Served (2017-2019) | 30% | 4.8 | 4.0 | 3.5 | 3.8
External Measures (2017-2019) | 30% | 80.6 | 88.4 | 96.1 | 86.2
External Nuclear Performance Indicators | 25% | 88.0 | 91.0 | 94.0 | 80.4
Media Tone % | 15% | 85.0 | 89.0 | 91.7 | 89.3
Stakeholder Survey % | 15% | 81.0 | 82.5 | 84.0 | 80.0
Customer Survey % | 15% | 64.7 | 66.3 | 68.0 | 71.3
Board Level Significant Events | 30% | -2.0 | 0.0 | 2.0 | 0.0
|  | Calculated Payout | 109%
Approved Payout | 116%

In August 2018, the TVA Board approved replacing the LTP financial measure Wholesale Rate Excluding Fuel with Non-Fuel Delivered Cost of Power for the future LTP awards. Wholesale Rate Excluding Fuel had not historically reflected TVA's financial performance as it is largely impacted by weather and customer behavior. The TVA Board and management believe that replacing the measure with Non-Fuel Delivered Cost of Power will drive performance through activities that management can influence.
The TVA Board used its discretion and adjusted payouts for the 2017 - 2019 performance cycle to 116% to better reflect goal achievement, overall strong performance and financial discipline.
Additional highlights of the 2017 - 2019 performance period include:

• | Strong financial performance reduced debt to the lowest level in almost 30 years and met the 10-year Long-Range Financial Plan goals in six years;

• | Strong transmission system reliability performances;

• | "Outstanding" customer survey results; and

• | Customer survey reflects high commitment levels.

As a result, the NEOs were awarded the following LTP payouts for the 2017 - 2019 performance cycle:

Named Executive Officers | Target LTP Grant Vesting September 30, 2019 |  | Calculated LTP Payout(2) |  | Approved LTP Payout(3)
Jeffrey J. Lyash | N/A |  |  | N/A |  |  | N/A |
William D. Johnson(1) | $ | 2,090,606 |  |  | $ | 2,278,761 |  |  | $ | 2,425,103 |
John M. Thomas, III | 750,000 |  |  | 817,500 |  |  | 870,000 |
Michael D. Skaggs | 750,000 |  |  | 817,500 |  |  | 870,000 |
Sherry A. Quirk | 675,000 |  |  | 735,750 |  |  | 783,000 |
Timothy S. Rausch | N/A |  |  | N/A |  |  | N/A |

Note
(1) Mr. Johnson's initial LTIP grant was in the amount of $2,427,800. He retired effective May 2, 2019. Based on the provisions of the LTIP Plan, Mr. Johnson's grant was prorated based on the 31 months (October 1, 2016 - April 30, 2019) he was employed during the performance cycle (October 1, 2016 - September 30, 2019).
(2) Amount based on calculated payout of 109%.
(3) Amount based on approved payout of 116%.
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Awards to the NEOs for the LTP performance cycle that ended September 30, 2019 are reported in the Summary Compensation Table. The amount of the award based on the calculated scorecard is reported as Non-Equity Incentive Plan Compensation. The discretionary adjustment ("LTP Scorecard Adjustment") is reported as a Bonus in the Summary Compensation Table.
2018 - 2020 Outstanding LTP Performance Cycle
The TVA Board approved the following overall LTP measures of TVA performance for all participants for the three-year cycle ending September 30, 2020 (awards to be paid in November 2020):

Performance Measure | Weight | Threshold (50%) | Target (100%) | Stretch (150%)
Non-Fuel Delivered Cost of Power(1) | 40% | 3.57 | 3.43 | 3.29
Load Not Served(2) | 30% | 4.8 Between top quartile and top decile | 4.0 2017 - 2019 average rate based on business plans | 3.6 Better than top decile
External Measures(3) | 30% | 81.6 | 89.4 | 97.1

Notes
(1) On August 22, 2018, the TVA Board approved replacing the Wholesale Rate Excluding Fuel measure with Non-Fuel Delivered Cost of Power for the 2018 - 2020 performance cycle because the Wholesale Rate Excluding Fuel measure has not historically reflected TVA's financial performance. The Non-Fuel Delivered Cost of Power measure is equal to the sum of (i) non-fuel operating and maintenance expense, (ii) base capital expense, (iii) interest expense, and (iv) other expense divided by budgeted electric power sales. For the 2018 - 2020 LTIP performance cycle, the Non-Fuel Delivered Cost of Power measure will be calculated using 2020 results.
(2) Load Not Served is equal to the product of (i) the percentage of total load not served and (ii) the number of minutes in the period (excluding interruptions due to declared major events). Value is expressed in system minutes and is the average of the three years within the LTIP performance cycle. Load Not Served events caused by TVA on a distributor system will also count as a TVA event even if TVA's system remains energized. For the 2018-2020 LTIP performance cycle, the Load Not Served measure will be calculated using an average of the 2018, 2019, and 2020 results. The target Load Not Served measure is the average of the rates for 2018, 2019 and 2020 that were set forth in the approved business plans for 2016, 2017, and 2018, respectively.
(3) For the 2018 - 2020 LTIP performance cycle, the External Measures metric will be calculated using an average of the 2018, 2019, and 2020 results (except for the External Nuclear Performance Indicators measure, which will be based on 2020 results). On August 25, 2016, the TVA Board revised (1) the method for calculating the External Nuclear Performance Indicators measure and (2) the goals related to this measure. The changes were adopted because the external party that rates the performance of TVA's nuclear fleet revised the industry standard metric for its rating index and provided new guidance on reporting requirements related to the addition of Watts Bar Unit 2 into TVA's nuclear fleet.
2019 - 2021 Outstanding LTP Performance Cycle
The TVA Board approved the following overall LTP measures of TVA performance for all participants for the three-year cycle ending September 30, 2021 (awards to be paid in November 2021):

Performance Measure | Weight | Threshold (50%) | Target (100%) | Stretch (150%)
Non-Fuel Delivered Cost of Power(1) | 40% | 3.57 | 3.44 | 3.30
Load Not Served(2) | 30% | 4.8 | 4.0 | 3.6
External Measures(3) | 30% | 82.0 | 89.8 | 97.5

Notes
(1) Non-Fuel Delivered Cost of Power measure is equal to the sum of (i) non-fuel operating and maintenance expense, (ii) base capital expense, (iii) interest expense, and (iv) other expense divided by budgeted electric power sales. For the 2019-2021 LTIP performance cycle, the Non-Fuel Delivered Cost of Power measure will be calculated using an average of the 2019, 2020, and 2021 results.
(2) Load Not Served is equal to the product of (i) the percentage of total load not served and (ii) the number of minutes in the period (excluding interruptions due to declared major events). Value is expressed in system minutes and is the average of the three years within the LTIP performance cycle. Load Not Served events caused by TVA on a distributor system will also count as a TVA event even if TVA's system remains energized. For the 2019 - 2021 LTIP performance cycle, the Load Not Served measure will be calculated using an average of the 2019, 2020, and 2021 results.
(3) For the 2019 - 2021 LTIP performance cycle, the External Measures metric will be calculated using an average of the 2019, 2020, and 2021 results (except for the External Nuclear Performance Indicators measure, which will be based on 2021 results).
Long-Term Retention. As a corporate agency of the U.S., TVA does not have equity securities that it can use to provide stock awards, options, or other equity-based awards as compensation for its employees. The purpose of the retention awards under the LTIP is to provide a retention incentive similar to restricted stock or restricted stock units. These grants are intended to encourage executives to remain with TVA and to provide, in combination with salary, EAIP, and LTP grants, a competitive level of total direct compensation. Awards are designed to constitute approximately 20 to 30 percent of each NEO's total long-term compensation. Grants are generally provided on October 1 and will become one-third vested on each subsequent September 30 or upon death, disability, or retirement if earlier on a pro-rated basis. Each award will be paid in a lump sum within two months of vesting.
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Following the market assessment conducted by FW Cook, effective October 1, 2018, TVA granted the following LTR awards under the LTIP:

Named Executive Officers | LTR/Long-Term Retention Grant(1)
Mr. Lyash(2) |  | N/A |
Mr. Johnson(3) |  | $ | 1,087,500 |
Mr. Thomas |  | 380,000 |
Mr. Skaggs |  | 420,000 |
Ms. Quirk |  | 290,000 |
Mr. Rausch |  | 173,250 |

Note
(1) Awards vest in three equal tranches on September 30, 2019, September 30, 2020, and September 30, 2021.
(2) Mr. Lyash did not receive a LTR grant because he was not employed on the date the grants were issued, October 1, 2018. He was eligible for a grant October 1, 2019.
(3) Mr. Johnson retired effective May 2, 2019. Based on the provisions of the LTIP, Mr. Johnson's LTR grants will be prorated based on the months he was employed during the vesting period.
Retirement Benefits. TVA sponsors a qualified defined benefit plan ("pension plan") and a qualified defined contribution plan ("401(k) plan"), which are administered by the TVA Retirement System ("TVARS"). The availability of, and level of benefits provided by, these qualified plans are comparable to similar qualified plans provided by companies in TVA's peer group.
In addition to its qualified retirement plans, TVA has a SERP for selected executives who are critical to the ongoing success of the enterprise. TVA's SERP is a non-qualified plan similar to those used by most other companies in its peer group. The purpose of the SERP is to:

• | Provide a competitive retirement benefit level that cannot be delivered solely through TVA's qualified retirement plans due to IRS limitations.

• | Provide a benefit level (as a percentage replacement of pre-retirement pay) that is more comparable to that of employees who are not subject to the IRS limitations.

More information regarding these retirement benefits is found following the Pension Benefits Table.
Health and Other Benefits. TVA offers a group of health and other benefits (medical, dental, vision, life and accidental death and disability insurance, and long-term disability insurance) that are available to a broad group of employees. The NEOs are eligible to participate in TVA's health benefit plans and other non-retirement benefit plans on the same terms and at the same contribution rates as other TVA employees.
CEO Compensation Matters. After a thorough review, including the consideration of CEO median compensation data, the Committee recommended that the TVA Board approve the compensation and incentive opportunities for Mr. Lyash upon commencement of his employment. Mr. Lyash receives an annual salary of $920,000 and a target annual incentive opportunity of 150 percent of his annual salary under the EAIP. He was eligible for an EAIP award for fiscal year 2019, and the amount of the award was prorated based on the number of months he was employed during the fiscal year and was based on individual and corporate performance.
Mr. Lyash is also a participant in the LTIP. Under the LTP component of the LTIP, Mr. Lyash's target grant opportunity is 220 percent of his annual salary. As described in his offer letter, effective October 1, 2019, Mr. Lyash received an initial LTP grant of $2,024,000 for the three-year performance cycle ending on September 30, 2021, and also received a LTP grant of $2,024,000 for the three-year performance cycle ending on September 30, 2022. Under the LTR component of the LTIP, Mr. Lyash's target opportunity is 95.2 percent of his annual salary beginning in fiscal year 2020. Based on an annual salary of $920,000, Mr. Lyash received a LTR grant of $876,000 for the three-year retention period ending on September 30, 2022, and the grant will vest in one-third increments as long as Mr. Lyash remains employed by TVA on the applicable vesting dates: $292,000 on September 30, 2020, $292,000 on September 30, 2021, and $292,000 on September 30, 2022, or upon death or disability if earlier.
Mr. Lyash also received a recruitment and relocation incentive of $1,784,000, which will vest and pay in three installments as long as Mr. Lyash remains employed by TVA on the applicable vesting dates: $400,000 on September 30, 2019, $1,092,000 on September 30, 2020, and $292,000 on September 30, 2021.
TVA also provided Mr. Lyash a sign-on bonus payment of $380,000, which was paid upon commencement of his employment. The sign-on bonus payment must be repaid in full to TVA if, within one year of the effective date of his employment, (1) he voluntarily terminates his employment, unless the separation is for reasons beyond his control and acceptable to TVA, or (2) he is terminated for cause.
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The chart below compares (i) the total direct compensation earned by Mr. Lyash for 2019; (ii) the target prorated compensation opportunity for Mr. Lyash for 2019; (iii) the 2019 approved target compensation opportunity for Mr. Lyash for 2019; (iv) the total direct compensation earned by Mr. Johnson for 2019; (v) the target prorated compensation opportunity for Mr. Johnson for 2019; (vi) the 2019 approved target compensation opportunity for Mr. Johnson for 2019; and (vii) the CEO median compensation data provided to the Committee by FW Cook, based on TVA's peer group as discussed above.

CEO Peer Group Compensation Comparison
Compensation Component | TVA CEO Lyash Actual Compensation for 2019 |  | TVA CEO Lyash Target Prorated Compensation Opportunity for 2019 |  | TVA CEO Lyash Target Compensation Opportunity for 2019 |  | TVA CEO Johnson Actual Compensation for 2019 |  | TVA CEO Johnson Target Prorated Compensation Opportunity for 2019 |  | TVA CEO Johnson Target Compensation Opportunity for 2019 |  | Chief Executive Officer Median Market Data(1)
Base Salary | $ | 445,846 |  | (2) | $ | 445,846 |  | (2) | $ | 920,000 |  |  | $ | 669,038 |  | (3) | $ | 669,038 |  | (3) | $ | 1,150,000 |  |  | $ | 1,238,000 |
Total Annual Incentive | 193 | % | (4) | 150 | % |  | 150 | % |  | 175 | % | (5) | 150 | % |  | 150% |  |  | 123 | %
Total Cash Compensation | $ | 1,307,815 |  |  | $ | 1,109,308 |  |  | $ | 2,300,000 |  |  | $ | 1,839,953 |  |  | $ | 1,678,447 |  |  | $ | 2,875,000 |  |  | $ | 2,773,000 |
Total Long-Term Incentive Compensation | — | % |  | — | % |  | — | % |  | 441 | % | (6) | 391% |  | (7) | 289% |  | (8) | 484% |
Sign-on Bonus | $ | 380,000 |  | (9) | $ | 380,000 |  | (9) | $ | 380,000 |  | (9) | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |
Recruitment/Relocation Incentive | $ | 400,000 |  | (10) | $ | 400,000 |  | (10) | $ | 400,000 |  | (10) | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |
Total Direct Compensation | $ | 2,087,815 |  |  | $ | 1,889,308 |  |  | $ | 3,080,000 |  |  | $ | 4,787,470 |  |  | $ | 4,291,467 |  |  | $ | 6,198,367 |  |  | $ | 8,709,000 |

Notes
(1) Target market assessment effective October 2018 and included market composite of Willis Towers Watson database and proxy peer group.
(2) Salary opportunity earned from April 8, 2019 through September 30, 2019.
(3) Salary opportunity earned from October 1, 2018 through May 2, 2019.
(4) Mr. Lyash's prorated EAIP Target Opportunity was $663,462. His award after applying the 1.0 Corporate Multiplier, 116% scorecard, and 112% Individual Performance Multiplier was $861,969.
(5) Mr. Johnson's prorated EAIP Target Opportunity was $1,009,409. His award after applying the 1.0 Corporate Multiplier, 116% scorecard, and 100% Individual Performance Multiplier was $1,170,915.
(6) Mr. Johnson's actual LTP award was $2,425,103 and the LTR prorated tranches were in the amount of $118,018, $192,938, and $211,458.
(7) Based on a retirement date of May 2, 2019, Mr. Johnson's prorated target LTP award was $2,090,606 and the LTR prorated tranches were in the amount of $118,018, $192,938, and $211,458.
(8) For the 2017-2019 LTP performance cycle, Mr. Johnson's target LTP award was $2,427,800 and he had three LTR tranches vesting in the amounts of $202,317, $330,750, and $362,500.
(9) Mr. Lyash received a $380,000 sign-on bonus associated with his hire.
(10) Mr. Lyash received a Recruitment/Relocation Incentive of $1,784,000 which vests in three installments - $400,000 on September 30, 2019, $1,092,000 on September 30, 2020, and $292,000 on September 30, 2021.
Executive Compensation Tables and Narrative Disclosures
Summary Compensation and Grants of Plan-Based Awards
The following table provides information on compensation earned by each of the Named Executive Officers in 2019 (and 2018 and 2017, as applicable).
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Summary Compensation Table
Name and Principal Position | Year | Salary |  | Bonus(1) |  | Non-Equity Incentive Plan Compensation(2) | Change in Pension Value and Nonqualified Deferred Compensation Earnings(3) | All Other Compensation(4) |  | Total
Jeffrey J. Lyash | 2019 | $ | 445,846 |  |  | $ | 380,000 |  |  | $ | 861,969 |  |  | $ | 5,970,873 |  |  | $ | 504,835 |  |  | $ | 8,163,523 |
President and Chief |  |  |  |  |  |  |  |  |  |  |  |
Executive Officer |  |  |  |  |  |  |  |  |  |  |  |
William D. Johnson, Retired | 2019 | $ | 669,038 |  |  | $ | 146,342 |  |  | $ | 3,972,090 |  |  | $ | 2,115,149 |  |  | $ | 33,000 |  |  | $ | 6,935,619 |
President and Chief | 2018 | 1,052,115 |  |  | — |  |  | 5,726,830 |  | (5) | 1,303,293 |  | (6) | 32,400 |  |  | 8,114,638 |
Executive Officer | 2017 | 995,000 |  |  | — |  |  | 4,075,857 |  | (7) | 1,556,084 |  | (8) | 31,800 |  |  | 6,658,741 |
John M. Thomas, III | 2019 | $ | 648,208 |  |  | $ | 52,500 |  |  | $ | 1,804,797 |  |  | $ | 1,076,752 |  |  | $ | 20,625 |  |  | $ | 3,602,882 |
Executive Vice President | 2018 | 629,023 |  |  | — |  |  | 1,692,318 |  | (9) | 173,723 |  | (10) | 20,250 |  |  | 2,515,314 |
and Chief Financial Officer | 2017 | 610,018 |  |  | — |  |  | 1,406,637 |  | (11) | 294,108 |  | (12) | 19,875 |  |  | 2,330,638 |
Mike D. Skaggs | 2019 | $ | 614,692 |  |  | $ | 52,500 |  |  | $ | 1,716,194 |  |  | $ | 2,017,130 |  |  | $ | 12,375 |  |  | $ | 4,412,891 |
Executive Vice President | 2018 | 520,951 |  |  | — |  |  | 1,422,133 |  | (13) | 320,678 |  | (14) | 12,150 |  |  | 2,275,912 |
and Chief Operating Officer | 2017 | 495,285 |  |  | — |  |  | 1,000,578 |  | (15) | 352,167 |  | (16) | 11,925 |  |  | 1,859,955 |
Sherry A. Quirk | 2019 | $ | 540,751 |  |  | $ | 47,250 |  |  | $ | 1,441,756 |  |  | $ | 401,540 |  |  | $ | 24,750 |  |  | $ | 2,456,047 |
Executive Vice President | 2018 | 511,254 |  |  | — |  |  | 1,288,900 |  | (17) | 207,166 |  | (18) | 24,300 |  |  | 2,031,620 |
and General Counsel | 2017 | 477,405 |  |  | — |  |  | 993,725 |  | (19) | 138,629 |  | (20) | 23,850 |  |  | 1,633,609 |
Timothy Rausch | 2019 | $ | 502,000 |  |  | $ | — |  |  | $ | 713,750 |  |  | $ | 72,784 |  |  | $ | 255,735 |  |  | $ | 1,544,269 |
Senior Vice President |  |  |  |  |  |  |  |  |  |  |  |
and Chief Nuclear Officer |  |  |  |  |  |  |  |  |  |  |  |

Note
(1) The 2019 data is outlined in the table below.

| Bonus
|  | Jeffrey J. Lyash |  | William D. Johnson |  | John M. Thomas, III |  | Michael D. Skaggs |  | Sherry A. Quirk |  | Timothy Rausch
| LTP Scorecard Adjustment | $ | — |  |  | $ | 146,342 |  |  | $ | 52,500 |  |  | $ | 52,500 |  |  | $ | 47,250 |  |  | $ | — |
| Sign-on Bonus | 380,000 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
| Total | $ | 380,000 |  |  | $ | 146,342 |  |  | $ | 52,500 |  |  | $ | 52,500 |  |  | $ | 47,250 |  |  | $ | — |

(2) The 2019 data is outlined in the table below.

| Non-Equity Incentive Plan Compensation
|  | Jeffrey J. Lyash |  | William D. Johnson |  | John M. Thomas, III |  | Michael D. Skaggs |  | Sherry A. Quirk |  | Timothy Rausch
| EAIP | $ | 861,969 |  |  | $ | 1,170,915 |  |  | $ | 660,630 |  |  | $ | 575,360 |  |  | $ | 439,340 |  |  | $ | 406,000 |
| LTP | — |  |  | 2,278,761 |  |  | 817,500 |  |  | 817,500 |  |  | 735,750 |  |  | — |
| LTR 2016-03(A) | — |  |  | 118,018 |  |  | 83,334 |  |  | 83,334 |  |  | 75,000 |  |  | — |
| LTR 2017-02(B) | — |  |  | 192,938 |  |  | 116,667 |  |  | 100,000 |  |  | 95,000 |  |  | — |
| LTR 2018-01(C) | — |  |  | 211,458 |  |  | 126,666 |  |  | 140,000 |  |  | 96,666 |  |  | 57,750 |
| Performance Incentive Arrangement ("PIA") | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 250,000 |
| Total | $ | 861,969 |  |  | $ | 3,972,090 |  |  | $ | 1,804,797 |  |  | $ | 1,716,194 |  |  | $ | 1,441,756 |  |  | $ | 713,750 |

Note
(A) LTR grant representing the third tranche of the LTR award effective October 1, 2016.
(B) LTR grant representing the second tranche of the LTR award effective October 1, 2017.
(C) LTR grant representing the first tranche of the LTR award effective October 1, 2018.
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(3) The 2019 data is outlined in the table below.

| Change in Pension Value and Nonqualified Deferred Compensation Earnings
|  | Jeffrey J. Lyash |  | William D. Johnson |  | John M. Thomas, III |  | Michael D. Skaggs |  | Sherry A. Quirk |  | Timothy Rausch
| Increase under TVARS Plans | $ | — |  |  | $ | 77,561 |  |  | $ | 60,304 |  |  | $ | 91,600 |  |  | $ | — |  |  | $ | — |
| Increase under SERP | 5,970,873 |  |  | 2,037,588 |  |  | 1,016,448 |  |  | 1,925,530 |  |  | 401,540 |  |  | 72,784 |
| Total | $ | 5,970,873 |  |  | $ | 2,115,149 |  |  | $ | 1,076,752 |  |  | $ | 2,017,130 |  |  | $ | 401,540 |  |  | $ | 72,784 |

(4) The 2019 data is outlined in the table below.

| All Other Compensation
|  | Jeffrey J. Lyash |  | William D. Johnson |  | John M. Thomas, III |  | Michael D. Skaggs |  | Sherry A. Quirk |  | Timothy Rausch
| 401(k) Matching Contribution | $ | 12,375 |  |  | $ | 16,500 |  |  | $ | 12,375 |  |  | $ | 12,375 |  |  | $ | 12,375 |  |  | $ | 12,375 |
| Non-Elective 401(k) Contribution | 12,375 |  |  | 16,500 |  |  | 8,250 |  |  | — |  |  | 12,375 |  |  | 12,375 |
| Recruitment/Relocation Incentive | 400,000 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 200,000 |
| Relocation Benefits | 80,085 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 30,985 |
| Total | $ | 504,835 |  |  | $ | 33,000 |  |  | $ | 20,625 |  |  | $ | 12,375 |  |  | $ | 24,750 |  |  | $ | 255,735 |

(5) Represents $2,354,625 awarded under the EAIP, $2,450,088 awarded under the LTIP, $722,117 awarded under LTR, and $200,000 awarded as a performance incentive arrangement ("PIA").
(6) Reflects increases of $2,969 under the Cash Balance Pension and $1,300,324 under the SERP.
(7) Represents $1,691,003 awarded under the EAIP, $1,793,488 awarded under the ELTIP, $391,366 awarded under the LTR, and $200,000 awarded as a PIA.
(8) Reflects increases of $3,588 under the Cash Balance Pension and $1,552,496 under the SERP.
(9) Represents $653,452 awarded under the EAIP, $772,200 awarded under the LTIP, and $266,666 awarded under the LTR.
(10) Reflects increases of $27,604 under the Cash Balance Pension and $146,119 under the SERP.
(11) Represents $502,654 awarded under the EAIP, $753,983 awarded under the ELTIP, and $150,000 awarded under the LTR.
(12) Reflects increases of $15,312 under the Cash Balance Pension and $278,796 under the SERP.
(13) Represents $540,800 awarded under the EAIP, $648,000 awarded under the LTIP, and $233,333 awarded under the LTR.
(14) Reflects increases of $49,607 under the Cash Balance Pension and $271,071 under the SERP.
(15) Represents $408,115 awarded under the EAIP, $459,130 awarded under the ELTIP, and $133,333 awarded under the LTR.
(16) Reflects increases of $37,091 under the Cash Balance Pension and $315,076 under the SERP.
(17) Represents $464,100 awarded under the EAIP, $604,800 awarded under the LTIP, and $220,000 awarded under the LTR.
(18) Reflects an increase of $207,166 under the SERP.
(19) Represents $344,210 awarded under the EAIP, $524,515 awarded under the ELTIP, and $125,000 awarded under the LTR.
(20) Reflects an increase of $138,629 under the SERP.
The following table provides information on non-equity incentive plan opportunities and grants provided to NEOs and the possible range of payouts associated with the opportunities and grants. Awards under the EAIP, LTP, LTR, and PIA that vested as of September 30, 2019, will be paid in cash during the first quarter of 2020.
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Grants of Plan-Based Awards Table as of September 30, 2019 |
|  | Estimated Possible Payouts Under Non-Equity Incentive Plan Awards(1) |  | Estimated Future Payouts Under Non-Equity Incentive Plan Awards(1) |  |  |
|  | Current Year |  | Future Years |  |  |
Name | Plan | Threshold(2) | Target(2) | Maximum(2) |  | Threshold(2) | Target(2) | Maximum(2) |  | Performance Period Ending/Vesting Date |
Jeffrey J. Lyash | EAIP(3) | $ | 331,731 |  | $ | 663,462 |  | $ | 995,193 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2018(7) |  |  |  |  | $ | 1,012,000 |  | 2,024,000 |  | 3,036,000 |  | (13) | 9/30/2021 |
William D. Johnson | EAIP(3) | $ | 504,705 |  | $ | 1,009,409 |  | $ | 1,514,114 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2016(4) | 1,045,303 |  | 2,090,606 |  | 3,135,909 |  | (8) |  |  |  |  | 9/30/2019 |
| LTR 2016-03(5) |  | 118,018 |  | 118,018 |  | (9) |  |  |  |  | 9/30/2019 |
| LTR 2017-02(5) |  | 192,938 |  | 192,938 |  | (10) |  |  |  |  | 9/30/2019 |
| LTR 2018-01(5) |  | 211,458 |  | 211,458 |  | (11) |  |  |  |  | 9/30/2019 |
| LTP 2017(6) |  |  |  |  |  | $ | 610,969 |  | $ | 1,221,938 |  | $ | 1,832,907 |  | (14) | 9/30/2020 |
| LTP 2018(7) |  |  |  |  |  | 246,702 |  | 493,403 |  | 740,105 |  | (15) | 9/30/2021 |
John M. Thomas, III | EAIP(3) | $ | 258,868 |  | $ | 517,735 |  | $ | 776,603 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2016(4) | 375,000 |  | 750,000 |  | 1,125,000 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2016-03(5) |  | 83,334 |  | 83,334 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2017-02(5) |  | 116,667 |  | 116,667 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2018-01(5) |  | 126,666 |  | 126,666 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2017(6) |  |  |  |  | $ | 425,000 |  | $ | 850,000 |  | $ | 1,275,000 |  |  | 9/30/2020 |
| LTR 2017-03(5) |  |  |  |  |  | 116,667 |  | 116,667 |  |  | 9/30/2020 |
| LTR 2018-02(5) |  |  |  |  |  |  | 126,667 |  | 126,667 |  |  | 9/30/2020 |
| LTP 2018(7) |  |  |  |  | 440,000 |  | 880,000 |  | 1,320,000 |  |  | 9/30/2021 |
| LTR 2018-03(5) |  |  |  |  |  | 126,667 |  | 126,667 |  |  | 9/30/2021 |
Michael D. Skaggs | EAIP(3) | $ | 248,000 |  | $ | 496,000 |  | $ | 744,000 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2016(4) | 375,000 |  | 750,000 |  | 1,125,000 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2016-03(5) |  | 83,334 |  | 83,334 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2017-02(5) |  | 100,000 |  | 100,000 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2018-01(5) |  | 140,000 |  | 140,000 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2017(6) |  |  |  |  | $ | 375,000 |  | $ | 750,000 |  | $ | 1,125,000 |  |  | 9/30/2020 |
| LTR 2017-03(5) |  |  |  |  |  | 100,000 |  | 100,000 |  |  | 9/30/2020 |
| LTR 2018-02(5) |  |  |  |  |  | 140,000 |  | 140,000 |  |  | 9/30/2020 |
| LTP 2018(7) |  |  |  |  | 490,000 |  | 980,000 |  | 1,470,000 |  |  | 9/30/2021 |
| LTR 2018-03(5) |  |  |  |  |  |  | 140,000 |  | 140,000 |  |  | 9/30/2021 |
Sherry A. Quirk | EAIP(3) | $ | 189,371 |  | $ | 378,741 |  | $ | 568,112 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2016(4) | $ | 337,500 |  | $ | 675,000 |  | $ | 1,012,500 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2016-03(5) |  | $ | 75,000 |  | $ | 75,000 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2017-02(5) |  | $ | 95,000 |  | $ | 95,000 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2018-01(5) |  | $ | 96,666 |  | $ | 96,666 |  |  |  |  |  |  | 9/30/2019 |
| LTP 2017(6) |  |  |  |  | $ | 337,500 |  | $ | 675,000 |  | $ | 1,012,500 |  |  | 9/30/2020 |
| LTR 2017-03(5) |  |  |  |  |  | 95,000 |  | 95,000 |  |  | 9/30/2020 |
| LTR 2018-02(5) |  |  |  |  |  | 96,667 |  | 96,667 |  |  | 9/30/2020 |
| LTP 2018(7) |  |  |  |  | 342,500 |  | 685,000 |  | 1,027,500 |  |  | 9/30/2021 |
| LTR 2018-03(5) |  |  |  |  |  |  | 96,667 |  | 96,667 |  |  | 9/30/2021 |
Timothy Rausch | EAIP(3) | $ | 175,000 |  | $ | 350,000 |  | $ | 525,000 |  |  |  |  |  |  | 9/30/2019 |
| PIA 2019 |  |  | 250,000 |  | (12) |  |  |  |  | 9/30/2019 |
| LTR 2018-01(5) |  | 57,750 |  | 57,750 |  |  |  |  |  |  | 9/30/2019 |
| LTR 2018-02(5) |  |  |  |  |  | $ | 57,750 |  | $ | 57,750 |  |  | 9/30/2020 |
| PIA 2019 |  |  |  |  |  |  | 350,000 |  | (12) | 9/30/2020 |
| LTP 2018(7) |  |  |  |  | $ | 202,125 |  | 404,250 |  | 606,375 |  |  | 9/30/2021 |
| LTR 2018-03(5) |  |  |  |  |  | 57,750 |  | 57,750 |  |  | 9/30/2021 |

Notes
(1) TVA does not have any equity securities and therefore has no equity-based awards.
(2) Threshold, Target, and Maximum represent amounts that could be earned by a NEO based on performance during the applicable performance cycle. Threshold, Target, and Maximum targets for EAIP and LTIP are 50 percent, 100 percent, and 150 percent.
(3) Target incentive opportunities as a percentage of salaries were as follows: Mr. Lyash, 150 percent; Mr. Johnson, 150 percent; Mr. Thomas, 80 percent; Mr. Skaggs, 80 percent; Ms. Quirk, 70 percent; and Mr. Rausch, 70 percent. Additionally, a corporate multiplier ranging between 0.00 and 1.00 may be applied which can reduce the award to $0. An individual performance multiplier of up to 125 percent may also be applied which may increase the award to 187.5
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percent of target. Actual EAIP awards earned for performance in 2019 are reported for each of the NEOs under the “Non-Equity Incentive Plan Compensation” column in the Summary Compensation Table. See Compensation Discussion and Analysis for a discussion of how each award was determined. Mr. Lyash, Mr. Johnson, and Mr. Rausch did not work a full year and their target incentive opportunities are prorated based on the number of days worked in the performance cycle. Details of the prorated target amounts are explained in the 2019 EAIP Payouts in the Compensation Discussion and Analysis.
(4) LTP awards were granted October 1, 2016, and vested September 30, 2019. At the end of the performance period, TVA's LTIP Scorecard was applied to the grants in order to determine award payouts. The amount of the award payout based on the calculated scorecard is reported for each of the NEOs under the “Non-Equity Incentive Plan Compensation” column in the Summary Compensation Table. The LTP Scorecard Adjustment is reported in the "Bonus" column in the Summary Compensation Table. In the case of death, the beneficiary will be paid as soon as administratively practicable but in no event later than the last day of the second full calendar month following the participant’s death. Disability awards will be paid as soon as administratively practicable but in no event later than the last day of the second full calendar month following the participant’s separation from service due to disability.
(5) All LTR awards will be paid in a lump sum within two months of the September 30th vesting date. The awards will be paid in cash after deducting applicable federal, state, and local withholding taxes. In the case of death, the beneficiary will be paid as soon as administratively practicable but in no event later than the last day of the second full calendar month following the participant’s death. Disability awards will be paid as soon as administratively practicable but in no event later than the last day of the second full calendar month following the participant’s separation from service due to disability. Actual LTR awards earned in 2019 are reported for each of the NEOs under the "Non-Equity Incentive Plan Compensation" column in the Summary Compensation Table.
(6) LTP awards were granted October 1, 2017, and will vest September 30, 2020. At the end of the performance period, TVA's LTIP Scorecard will be applied to the grants in order to determine award payouts. The final award may be adjusted by the Board based on the evaluation of the participant's individual achievements, peer group comparisons, and performance results over the performance cycle.
(7) LTP awards were granted October 1, 2018, and will vest September 30, 2021. At the end of the performance period, TVA's LTIP Scorecard will be applied to the grants in order to determine award payouts. The final award may be adjusted by the Board based on the evaluation of the participant's individual achievements, peer group comparisons, and performance results over the performance cycle.
(8) Reflects prorated amount of 31/36ths of initial $2,427,800 grant based on Mr. Johnson’s retirement date of May 2, 2019.
(9) Reflects prorated amount of 7/12ths of $202,317 tranche vesting September 30, 2019, based on Mr. Johnson’s retirement date of May 2, 2019.
(10) Reflects prorated amount of 7/12ths of $330,750 tranche vesting September 30, 2019, based on Mr. Johnson’s retirement date of May 2, 2019.
(11) Reflects prorated amount of 7/12ths of $362,500 tranche vesting September 30, 2019, based on Mr. Johnson’s retirement date of May 2, 2019.
(12) Reflects the maximum award Mr. Rausch was eligible to receive under a Performance Incentive Arrangement (“PIA”). The actual award to be paid to Mr. Rausch is reported in the “Non-Equity Incentive Plan Compensation” column of the Summary Compensation Table.
(13) Mr. Lyash’s employment offer includes a LTP grant of $2,024,000 effective October 1, 2019. Although this grant was not effective in FY 2019, it is included in this table as it is a compensation obligation.
(14) Reflects prorated amount of 19/36ths of initial $2,315,250 grant based on Mr. Johnson’s retirement date of May 2, 2019.
(15) Reflects prorated amount of 7/36ths of initial $2,537,500 grant based on Mr. Johnson’s retirement date of May 2, 2019.
Retirement and Pension Plans
The table below provides the actuarial present value of the Named Executive Officers' accumulated benefits, including the number of years of credited service, under TVA's retirement and pension plans as of September 30, 2019, determined using a methodology and interest rate and mortality rate assumptions consistent with those used in the financial statements in this Annual Report, set forth in Note 21 — Benefit Plans.

Pension Benefits Table
Name | Plan Name | Number of Years of Credited Service(1) |  | Present Value of Accumulated Benefit |  | Payments During Last Year
Jeffrey J. Lyash | TVARS | N/A |  | N/A |  | (5) | $ | — |
| SERP Tier 1 | 10.417 | (2) | $ | 5,970,873 |  |  | — |
William D. Johnson | TVARS | 6.333 | (3) | 152,692 |  |  | 2,790 |
| SERP Tier 1 | 12.333 | (3) | 7,862,385 |  |  | 2,053,334 |
John M. Thomas, III | TVARS | 13.833 |  | 377,548 |  |  | — |
| SERP Tier 1 | 13.833 |  | 3,689,040 |  |  | — |
Michael D. Skaggs | TVARS | 25.583 |  | 717,549 |  |  | — |
| SERP Tier 1 | 24.000 | (4) | 6,339,127 |  |  | — |
Sherry A. Quirk | TVARS | N/A |  | N/A |  | (5) | — |
| SERP Tier 1 | 4.583 |  | 749,598 |  |  | — |
Timothy Rausch | TVARS | N/A |  | N/A |  | (5) | — |
| SERP Tier 2 | 0.917 |  | 72,784 |  |  | — |

Notes
(1) Limited to 24 years when determining supplemental benefits available under SERP Tier 1, described below.
(2) Mr. Lyash was granted five years of credited service for calculating his SERP benefit. In the event of involuntary termination except for cause prior to five years of actual service, the vesting requirement will be waived and he will be entitled to the additional five years of granted credited service plus his actual years of service for calculating his SERP benefit. In the event of termination for cause or voluntary termination for any reason prior to five years of actual service, the vesting requirement will be waived and his SERP benefit will be calculated based on a total of five years of credited service. After five years of actual service with TVA, he will be granted five additional years of credited service for a total of 15 years of credited service for calculating his SERP benefit. As of September 30, 2019, Mr. Lyash had .417 years of service. The Present Value of the Accumulated SERP benefit with 5.417 years of credited service is $3,049,044. The Present Value of the Accumulated SERP benefit with 10.417 years of credited service is $5,970,873. This number is reported in the Summary Compensation Table.
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(3) Mr. Johnson was granted five additional years of credited service for pre-TVA employment because he was employed with TVA for at least five years and satisfied the minimum five-year vesting requirement; therefore, the offset for prior employer pension benefits associated with the additional five years of credited service was waived. In addition, the offset for benefits provided under TVA’s defined benefit plan will be calculated based on the benefit he would be eligible to receive as a participant in the Cash Balance Pension taking into account the additional years of credited service being used for SERP benefit calculation purposes. In December 2016, the TVA Board approved amendments to Mr. Johnson’s compensation arrangements to provide, among other things, that if Mr. Johnson remained with TVA through calendar year 2018, his SERP benefit would be based on 12 years credited service (six credited years and six actual years).
(4) Mr. Skaggs has reached the 24 year service cap allowed under the Plan.
(5) Mr. Lyash, Ms. Quirk, and Mr. Rausch are not eligible to participate in the TVARS Pension Plan since they were hired after June 30, 2014.
Qualified Retirement Plans
The retirement benefits for which employees are eligible and receive under the TVARS pension plan and 401(k) plan depend on the employee's hire date, years of service, and individual elections, as follows:

• | Employees who were first hired prior to January 1, 1996, receive (i) a traditional pension benefit calculated based on the employee's creditable service, the employee's average monthly salary for the highest three consecutive years of eligible compensation, and a pension factor based on the employee's age and years of service, less a Social Security offset, and (ii) 401(k) plan matching contributions from TVA. The 401(k) plan matching contribution is $0.25 on every dollar contributed by the employee up to 1.5 percent of eligible compensation. None of the Named Executive Officers are in this group.

• | Employees who were first hired prior to January 1, 1996, and who elected to switch pension structures from traditional to cash balance, receive (i) a cash balance pension benefit calculated based on (a) pay-based credits and interest that accrue over time in the employee's account and (b) the employee's age at the time of retirement, and (ii) 401(k) plan matching contributions from TVA. The monthly pay credits are equal to six percent of eligible compensation, and monthly interest is credited at an annual interest rate equal to the change in the CPI-U plus three percent (with a minimum of six percent and maximum of 10 percent). The interest rate during 2019 was six percent. The 401(k) plan matching contribution is $0.75 on every dollar contributed by the employee up to 4.5 percent of eligible compensation.

Mr. Skaggs is in this group.

• | Employees who were first hired on or after January 1, 1996, and who had 10 or more years of service as of October 1, 2016, receive (i) a cash balance pension benefit calculated based on (a) pay-based credits and interest that accrue over time in the employee's account and (b) the employee's age at the time of retirement, and (ii) 401(k) plan non-elective and matching contributions from TVA. The monthly pay credits are equal to three percent of eligible compensation, and monthly interest is credited at an annual interest rate equal to the change in the CPI-U plus two percent (with a minimum of 4.75 percent and a maximum of 6.25 percent). The interest rate during 2019 was 4.75 percent. The 401(k) plan automatic, non-elective contribution is equal to three percent of eligible compensation, and the matching contribution is $0.75 on every dollar contributed by the employee up to 4.5 percent of eligible compensation. Mr. Thomas is in this group.

• | Employees who were first hired on or after January 1, 1996, and who had less than 10 years of service as of October 1, 2016, receive (i) a cash balance pension benefit calculated based on pay-based credits and interest that accrue over time in the employee's account and the employee's age at the time of retirement, and (ii) 401(k) plan non-elective and matching contributions from TVA. As of October 1, 2016, the cash balance accounts of these employees receive no additional pay-based credits; however, the accounts continue to receive monthly interest credits at an annual interest rate equal to the change in the CPI-U plus two percent (with a minimum of 4.75 percent and a maximum of 6.25 percent). The interest rate during 2019 was 4.75 percent. The 401(k) plan automatic, non-elective contribution is equal to six percent of eligible compensation, and the matching contribution is dollar-for-dollar on employee contributions up to six percent of eligible compensation. Mr. Johnson was in this group.

• | Employees who were hired prior to July 1, 2014, and who elected to waive their cash balance retirement benefit and transfer their cash balance account to the 401(k) plan effective October 1, 2018, receive a retirement benefit in the 401(k) plan only. The 401(k) plan is an automatic, non-elective contribution that is equal to six percent of eligible compensation, and the matching contribution is dollar-for-dollar on employee contributions up to six percent of the eligible compensation. None of the NEOs are in this group.

• | Employees who were first hired on or after July 1, 2014 (or who were rehired and were either previously not vested in the pension plan or cashed out their pension benefit) receive a retirement benefit in the 401(k) plan only. The 401(k) plan automatic, non-elective contribution is equal to 4.5 percent of eligible compensation, and the matching contribution is $0.75 on every dollar contributed by the employee up to 4.5 percent of eligible compensation. Mr. Lyash, Mr. Rausch and Ms. Quirk are in this group.

Cash Balance Pension. For NEOs who are eligible for retirement benefits under the pension plan, which includes Mr. Johnson, Mr. Thomas, and Mr. Skaggs, eligible compensation is defined as annual salary only for benefit calculation purposes and is shown under the column titled "Salary" in the Summary Compensation Table. The eligible compensation in 2019 could not exceed $275,000 pursuant to the IRS annual compensation limit applicable to qualified plans. Employees with cash balance benefits who have at least five years of cash balance service are eligible at retirement or termination of employment to receive
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an immediate benefit in the form of a monthly pension with survivor benefit options or in a lump-sum payment with cash out or rollover options. The pension plan does not provide for early retirement benefits to any NEO or any other employee eligible for cash balance benefits.
401(k) Plan. All employees eligible to participate in the 401(k) plan, including the NEOs, may elect to contribute to the 401(k) plan on a before-tax, Roth, and/or after-tax basis. For purposes of matching and non-elective contributions from TVA to the 401(k) accounts of the NEOs, eligible compensation is defined as annual salary only for benefit calculation purposes and is shown under the column titled "Salary" in the Summary Compensation Table. The eligible compensation in 2019 could not exceed $275,000 pursuant to the IRS annual compensation limit applicable to qualified plans. Any participant in the 401(k) plan must have three years of TVA service to be vested in matching and non-elective contributions from TVA.
Supplemental Executive Retirement Plan
All NEOs are participants in the SERP. The SERP is a non-qualified defined benefit pension plan similar to those typically found in other companies in TVA's peer group and is provided to a limited number of executives, including the NEOs. TVA's SERP was created to recruit and retain key executives. The plan is designed to provide a competitive level of retirement benefits in excess of the limitations on contributions and benefits imposed by TVA's qualified defined benefit plan and Internal Revenue Code Section 415 limits on qualified retirement plans.
The SERP provides two distinct levels of participation, Tier 1 and Tier 2. Each participant is assigned to one of the two tiers at the time he or she is approved to participate in the SERP. The level of participation ("Tier") defines the level of retirement benefits under the SERP at the time of retirement.
Under the SERP, normal retirement eligibility is age 62 with five years of vesting service. No vested and accrued benefits are payable prior to age 55, and benefits are reduced for retirements prior to age 62. The level of reduction in benefits for retirements prior to age 62 depends on whether a participant's termination is "approved" or "unapproved." In the event of an approved termination of TVA employment, any vested and accrued benefits are reduced by 5/12 percent for each month that the date of benefit commencement precedes the participant's 62nd birthday, up to a maximum reduction of 35 percent. In the event of an unapproved termination of TVA employment, the participant's accrued benefits are first subject to a reduced percentage of vesting if the participant's years of service are between five and 10. At five years of vesting service, the vested percentage of retirement benefits is 50 percent and increases thereafter by 10 percent for each full additional year of service, reaching 100 percent vesting for 10 or more years of vesting service. Thereafter, any vested and accrued benefits are reduced by 10/12 percent for each month that the date of benefit commencement precedes the participant's 62nd birthday up to a maximum reduction of 70 percent.
For purposes of the SERP, an "approved" termination means termination of employment with TVA due to (i) retirement on or after the participant's 62nd birthday, (ii) retirement on or after attainment of actual age 55, if such retirement has the approval of the TVA Board or its delegate, (iii) death in service as an employee, (iv) disability (as defined under the Rules and Regulations of the TVARS) as determined by the Retirement Committee, or (v) any other circumstance approved by the TVA Board or its delegate. For purposes of the SERP, an "unapproved" termination means a termination of employment with TVA when such termination does not constitute an "approved" termination as defined in the preceding sentence.
SERP Tier 1. The Tier 1 structure is designed to replace 60 percent of the amount of a participant's compensation at the time the participant reaches age 62 and has accrued 24 years of TVA service. Tier 1 benefits are based on a participant's highest average compensation during three consecutive SERP years and a pension multiple of 2.5 percent for each year of credited service up to a maximum of 24 years. Compensation is defined as salary and EAIP for benefit calculation purposes. Tier 1 benefits are offset by Social Security benefits, benefits provided under TVA's qualified defined benefit pension plan, and prior employer pension benefits when applicable.
SERP Tier 2. The purpose of this restoration plan is to adjust qualified plan benefits to executives when benefits are lost due to IRS limits. Pension benefits are based on a participant's average compensation over three consecutive fiscal years and a pension multiplier of 1.3 percent for each year of service. For benefit calculation, pension includes salary and annual incentives.
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Nonqualified Deferred Compensation
The following table provides information regarding deferred contributions, earnings, and balances for each of the NEOs. The amounts reported under this table do not represent compensation in addition to the compensation that was earned in 2019 and already reported in the Summary Compensation Table, but rather the amounts of compensation earned by the NEOs in 2019 or prior years that were or have been deferred.

Nonqualified Deferred Compensation Table |
Name | Executive Contributions in 2019 | Registrant Contributions in 2019 |  | Aggregate Earnings in 2019 |  | Aggregate Withdrawals/ Distributions |  | Aggregate Balance at September 30, 2019 |
Jeffrey J. Lyash | $ | — |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |
William D. Johnson | — |  | — |  |  | — |  |  | — |  |  | — |  |
John M. Thomas, III | — |  | — |  |  | — |  |  | — |  |  | — |  |
Michael D. Skaggs | — |  | — |  |  | 213,467 |  | (1) | — |  |  | 4,988,460 |  | (2)
Sherry A. Quirk | — |  | — |  |  | — |  |  | — |  |  | — |  |
Timothy Rausch | — |  | — |  |  | — |  |  | — |  |  | — |  |

Notes
(1) Includes vested earnings. Because none of the amounts are above market or preferential earnings under SEC rules, none of these amounts are included in the Summary Compensation Table.
(2) Includes vested contributions and earnings. $600,000 of this amount has been reported in the Summary Compensation Table as compensation for a prior fiscal year.
TVA's compensation plans may allow participants to defer all or a portion of compensation earned under the plans as defined by plan terms and IRS regulations. All deferrals are credited to each participant in a deferred compensation account, and the deferral amounts are then funded into a rabbi trust. Each participant may elect one or more investment options made available by TVA or allow some or all funds to accrue interest at the rate established by the beginning of each fiscal year equal to the composite rate of all Treasury issues. Participants may elect to change from either one notional investment option or the TVA interest bearing option to another at any time. Upon termination of employment, funds are distributed pursuant to elections made in accordance with applicable IRS regulations.
Participants in the EAIP and LTIP, including the NEOs, were not allowed to elect to defer any portion of their awards received under the plans for 2019.
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Potential Payments on Account of Retirement/Resignation, Termination without Cause, Termination with Cause, Death, or Disability
The tables below show certain potential payments that would have been made to each NEO if his or her employment had been terminated on September 30, 2019, under various scenarios. All of the Named Executive Officers would also be entitled to payments from plans generally available to TVA employees under the specific circumstances of termination of employment, including the health and welfare and pension plans and amounts in the 401(k) plan.

Jeffrey J. Lyash | Retirement/Resignation |  | Termination without Cause |  | Termination with Cause |  | Death |  | Disability |
Severance Agreement(1) | $ | — |  |  | $ | 2,300,000 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |
SERP(2) | 2,793,923 |  |  | 3,049,044 |  |  | 2,793,923 |  |  | 3,049,044 |  | (3) | 3,049,044 |  |
EAIP | 861,969 |  |  | 861,969 |  |  | 861,969 |  |  | 861,969 |  |  | 861,969 |  |
Recruitment/Relocation Incentive(4) | 400,000 |  |  | 400,000 |  |  | 400,000 |  |  | 400,000 |  |  | 400,000 |  |
LTP | — |  |  | — |  |  | — |  |  | 281,111 |  | (5) | 281,111 |  | (6)
Deferred Compensation | — |  |  | — |  |  | — |  |  | — |  |  | — |  |
Total Value of Potential Payments | $ | 4,055,892 |  |  | $ | 6,611,013 |  |  | $ | 4,055,892 |  |  | $ | 4,592,124 |  |  | $ | 4,592,124 |  |

Notes
(1) In February 2019, TVA entered into an arrangement with Mr. Lyash that provides a lump-sum payment equal to one year’s annual salary and one year’s executive annual incentive based on 100 percent target payout in the event TVA terminates his employment without cause. For purposes of this provision, termination without cause includes constructive termination which will be deemed to occur if Mr. Lyash terminates his employment because he is asked to take a new position with TVA with a material reduction in level of authority, duties, compensation, and benefits. This provision will not apply, and no lump-sum payment will be made, in the event Mr. Lyash voluntarily terminates his employment or voluntarily retires, or his employment is terminated “for cause” as defined in the agreement.
(2) In February 2019, TVA entered into an arrangement with Mr. Lyash that provides that at the commencement of his employment with TVA, he will be granted five years of credited service for calculating his SERP benefit. In the event of involuntary termination except for cause prior to five years of actual service, the vesting requirement will be waived and he will be entitled to the additional five years of granted credited service plus his actual years of service for calculating his SERP benefit. In the event of termination for cause or voluntary termination for any reason prior to five years of actual service, the vesting requirement will be waived and his SERP benefit will be calculated based on a total of five years of credited service.
(3) In the event of death while employed by TVA, the beneficiary will receive a lump sum payment equal to the actuarial equivalent of the benefit that would have been paid had the participant terminated employment on the date of death and elected a joint and 50 percent survivor benefit. Survivor will receive 50 percent of the reported value.
(4) Mr. Lyash received a Recruitment/Relocation Incentive of $1,784,000 upon employment, and $400,000 of this amount vested on September 30, 2019.
(5) The LTIP provides that in the event of the death of a participant, the participant’s beneficiary is entitled to (1) any LTP award that had vested at the time of the participant’s death but not been paid and (2) any LTP awards that had not vested at the time of the participant’s death and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was participating in the plan during the applicable performance cycle.
(6) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to (1) any LTP award that had vested at the time of the participant’s separation from service but not been paid and (2) any LTP awards that had not vested at the time of the participant’s separation from service and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was employed by TVA during the applicable performance cycle.
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John M. Thomas, III | Retirement/Resignation |  | Termination without Cause |  | Termination with Cause |  | Death |  | Disability |
Severance Agreement(1) | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |
SERP | 3,689,040 |  | (2) (3) (4) | 3,689,040 |  | (2) (3) (4) | 3,689,040 |  | (2) (3) (4) | 3,689,040 |  | (2) (5) | 3,689,040 |  | (2)(3)
EAIP | 660,630 |  |  | 660,630 |  |  | 660,630 |  |  | 660,630 |  |  | 660,630 |  |
LTR | 326,667 |  |  | 326,667 |  |  | 326,667 |  |  | 490,556 |  | (6) | 490,556 |  | (7)
LTP | 870,000 |  | (8) | 870,000 |  |  | 870,000 |  |  | 1,730,000 |  | (9) | 1,730,000 |  | (10)
Deferred Compensation | — |  |  | — |  |  | — |  |  | — |  |  | — |  |
Total Value of Potential Payments | $ | 5,546,337 |  |  | $ | 5,546,337 |  |  | $ | 5,546,337 |  |  | $ | 6,570,226 |  |  | $ | 6,570,226 |  |

Notes
(1) Mr. Thomas does not have a severance agreement with TVA.
(2) Represents the present value of the accumulated benefit.
(3) Actual benefit would be paid in five annual installments beginning at age 55.
(4) Assumes that the TVA Board or its delegate determines that the termination is an approved termination under SERP. See Retirement and Pension Plans — Supplemental Executive Retirement Plan above for a discussion of approved and unapproved terminations under SERP.
(5) In the event of death while employed by TVA, the beneficiary would receive a lump sum payment equal to the actuarial equivalent of the benefit that would have been paid had the participant terminated employment on the date of death and elected a joint and 50 percent survivor benefit. Survivor will receive 50 percent of the reported value.
(6) The LTIP provides that in the event of the death of a participant, the participant's beneficiary is entitled to any portion of a LTR award that had vested at the time of the participant's death but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant's separation from service, provided that the LTR award for each vesting period will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(7) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to any portion of a LTR award that had vested at the time of the separation from service but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant's separation from service, provided that the LTR award will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(8) In the event of retirement, Mr. Thomas will receive $870,000 upon retirement, two-thirds of the actual LTP award that vests on September 30, 2020, and one-third of the actual LTP award that vests on September 30, 2021.
(9) The LTIP provides that in the event of the death of a participant, the participant's beneficiary is entitled to (1) any LTP award that had vested at the time of the participant's death but not been paid and (2) any LTP awards that had not vested at the time of the participant's death and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was participating in the plan during the applicable performance cycle.
(10) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to (1) any LTP award that had vested at the time of the participant's separation from service but not been paid and (2) any LTP awards that had not vested at the time of the participant's separation from service and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was employed by TVA during the applicable performance cycle.
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Michael D. Skaggs | Retirement/Resignation |  | Termination without Cause |  | Termination with Cause |  | Death |  | Disability |
Severance Agreement(1) | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |
SERP | 6,339,127 |  | (2) (3) (4) | 6,339,127 |  | (2) (3) (4) | 6,339,127 |  | (2) (3) (4) | 6,339,127 |  | (2) (5) | 6,339,127 |  | (2) (3)
EAIP | 575,360 |  |  | 575,360 |  |  | 575,360 |  |  | 575,360 |  |  | 575,360 |  |
LTR | 323,334 |  |  | 323,334 |  |  | 323,334 |  |  | 490,001 |  | (6) | 490,001 |  | (7)
LTP | 870,000 |  | (8) | 870,000 |  |  | 870,000 |  |  | 1,696,667 |  | (9) | 1,696,667 |  | (10)
Deferred Compensation(11) | 4,988,460 |  |  | 4,988,460 |  |  | 4,988,460 |  |  | 4,988,460 |  |  | 4,988,460 |  |
Total Value of Potential Payments | $ | 13,096,281 |  |  | $ | 13,096,281 |  |  | $ | 13,096,281 |  |  | $ | 14,089,615 |  |  | $ | 14,089,615 |  |

Notes
(1) Mr. Skaggs does not have a severance agreement with TVA.
(2) Represents the present value of the accumulated benefit.
(3) Actual benefit would be paid in ten annual installments beginning on the date of Mr. Skaggs' separation from service.
(4) Assumes that the TVA Board or its delegate determines that the termination is an approved termination under SERP. See Retirement and Pension Plans — Supplemental Executive Retirement Plan above for a discussion of approved and unapproved terminations under SERP.
(5) In the event of death while employed by TVA, the beneficiary would receive a lump sum payment equal to the actuarial equivalent of the benefit that would have been paid had the participant terminated employment on the date of death and elected a joint and 50 percent survivor benefit. Survivor will receive 50 percent of the reported value.
(6) The LTIP provides that in the event of the death of a participant, the participant's beneficiary is entitled to any portion of a LTR award that had vested at the time of the participant's death but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant's separation from service, provided that the LTR award for each vesting period will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(7) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to any portion of a LTR award that had vested at the time of the separation from service but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant's separation from service, provided that the LTR award will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(8) In the event of retirement, Mr. Skaggs will receive $870,000 upon retirement, two-thirds of the actual LTP award that vests on September 30, 2020, and one-third of the actual LTP award that vests on September 30, 2021.
(9) The LTIP provides that in the event of the death of a participant, the participant's beneficiary is entitled to (1) any LTP award that had vested at the time of the participant's death but not been paid and (2) any LTP awards that had not vested at the time of the participant's death and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was participating in the plan during the applicable performance cycle.
(10) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to (1) any LTP award that had vested at the time of the participant's separation from service but not been paid and (2) any LTP awards that had not vested at the time of the participant's separation from service and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was employed by TVA during the applicable performance cycle.
(11) Amounts that Mr. Skaggs earned in past years but elected to defer, which are payable pursuant to elections he made and applicable IRS rules.
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Sherry A. Quirk | Retirement/Resignation |  | Termination without Cause |  | Termination with Cause |  | Death |  | Disability |
Severance Agreement(1) | $ | — |  |  | $ | 541,049 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |
SERP | — |  | (2) | — |  | (2) | — |  | (2) | 749,598 |  | (3) (4) | 749,598 |  | (3)
EAIP | 439,340 |  |  | 439,340 |  |  | 439,340 |  |  | 439,340 |  |  | 439,340 |  |
LTR | 266,666 |  |  | 266,666 |  |  | 266,666 |  |  | 394,721 |  | (5) | 394,721 |  | (6)
LTP | 783,000 |  |  | 783,000 |  |  | 783,000 |  |  | 1,461,333 |  | (7) | 1,461,333 |  | (8)
Deferred Compensation | — |  |  | — |  |  | — |  |  | — |  |  | — |  |
Total Value of Potential Payments | $ | 1,489,006 |  |  | $ | 2,030,055 |  |  | $ | 1,489,006 |  |  | $ | 3,044,992 |  |  | $ | 3,044,992 |  |

Notes
(1) In December 2014, TVA entered into an arrangement with Ms. Quirk that provides a lump-sum payment equal to one year's annual salary in the event TVA terminates her employment without cause.
(2) The five-year vesting requirement has not been met.
(3) Represents the present value of the accumulated benefit.
(4) In the event of death while employed by TVA, the beneficiary would receive a lump sum payment equal to the actuarial equivalent of the benefit that would have been paid had the participant terminated employment on the date of death and elected a joint and 50 percent survivor benefit. Survivor will receive 50 percent of the reported value.
(5) The LTIP provides that in the event of the death of a participant, the participant's beneficiary is entitled to any portion of a LTR award that had vested at the time of the participant's death but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant's separation from service, provided that the LTR award for each vesting period will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(6) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to any portion of a LTR award that had vested at the time of the separation from service but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant's separation from service, provided that the LTR award will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(7) The LTIP provides that in the event of the death of a participant, the participant's beneficiary is entitled to (1) any LTP award that had vested at the time of the participant's death but not been paid and (2) any LTP awards that had not vested at the time of the participant's death and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was participating in the plan during the applicable performance cycle.
(8) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to (1) any LTP award that had vested at the time of the participant's separation from service but not been paid and (2) any LTP awards that had not vested at the time of the participant's separation from service and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was employed by TVA during the applicable performance cycle.
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Timothy Rausch | Retirement/Resignation |  | Termination without Cause |  | Termination with Cause |  | Death |  | Disability |
Severance Agreement(1) | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |
SERP | — |  | (2) | — |  | (2) | — |  | (2) | 72,784 |  | (3) (4) | 72,784 |  | (3)
EAIP | 406,000 |  |  | 406,000 |  |  | 406,000 |  |  | 406,000 |  |  | 406,000 |  |
LTR | 57,750 |  |  | 57,750 |  |  | 57,750 |  |  | 105,875 |  | (5) | 105,875 |  | (6)
LTP | — |  |  | — |  |  | — |  |  | 134,750 |  | (7) | 134,750 |  | (8)
Deferred Compensation | — |  |  | — |  |  | — |  |  | — |  |  | — |  |
Total Value of Potential Payments | $ | 463,750 |  |  | $ | 463,750 |  |  | $ | 463,750 |  |  | $ | 719,409 |  |  | $ | 719,409 |  |

Notes
(1) Mr. Rausch does not have a severance agreement with TVA.
(2) The five-year vesting requirement has not been met.
(3) Represents the present value of the accumulated benefit.
(4) In the event of death while employed by TVA, the beneficiary will receive a lump sum payment equal to the actuarial equivalent of the benefit that would have been paid had the participant terminated employment on the date of death and elected a joint and 50 percent survivor benefit. Survivor will receive 50 percent of the reported value.
(5) The LTIP provides that in the event of the death of a participant, the participant’s beneficiary is entitled to any portion of a LTR award that had vested at the time of the participant’s death but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant’s separation from service, provided that the LTR award for each vesting period will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(6) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to any portion of a LTR award that had vested at the time of the separation from service but not been paid as well as a prorated portion of any LTR grant that had not vested at the time of the participant’s separation from service, provided that the LTR award will be prorated based on the number of whole months the participant was employed by TVA during the vesting period in which the participant separated from service as compared to (a) 12 months for the vesting period that includes the day that the participant separated from service, (b) 24 months for the vesting period that immediately follows the vesting period during which the participant separated from service, and (c) 36 months for the second vesting period that follows the vesting period during which the participant separated from service.
(7) The LTIP provides that in the event of the death of a participant, the participant’s beneficiary is entitled to (1) any LTP award that had vested at the time of the participant’s death but not been paid and (2) any LTP awards that had not vested at the time of the participant’s death and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was participating in the plan during the applicable performance cycle.
(8) The LTIP provides that if a participant separates from service due to a disability, the participant is entitled to (1) any LTP award that had vested at the time of the participant’s separation from service but not been paid and (2) any LTP awards that had not vested at the time of the participant’s separation from service and that covered a performance cycle for which the participant had received a LTP grant, provided that the amount of any such LTP award (a) will be calculated assuming that the percent of opportunity achieved is 100 percent of target and (b) will be prorated based on the number of whole months the participant was employed by TVA during the applicable performance cycle.
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Post-Retirement Payments for Mr. Johnson

William D. Johnson (1) | Payments for 2019 |  | Estimated Payments After 2019 |
Severance Agreement | $ | — |  |  | $ | — |  |
SERP | 2,053,334 |  | (2) | 7,862,385 |  | (3)
EAIP | 1,170,915 |  | (4) | — |  |
LTR | 522,414 |  | (4) | — |  |
LTP | 2,425,103 |  | (4) | 1,715,341 |  | (5)
Deferred Compensation | — |  |  | — |  |
Total Value | $ | 6,171,766 |  |  | $ | 9,577,726 |  |

Notes

(1) | Mr. Johnson retired from TVA on May 2, 2019.

(2) | Represents the first SERP benefit installment (one of five) paid within 60 days following retirement.

(3) | Represents the present value of the accumulated benefit, as of September 30, 2019, to be paid in four remaining annual installments.

(4) | The payment will be made in November or December of 2019.

(5) | Mr. Johnson will receive 19/36ths of the actual LTP award that vests on September 30, 2020, and 7/36ths of the actual LTP award that vests on September 30, 2021. Assuming 100 percent payout, these amounts will be $1,221,938 and $493,403, respectively.

Other Agreements
Except as described above and in the Compensation Discussion and Analysis, there are no other agreements between TVA and any of the NEOs.
CEO Pay Ratio Disclosure
As required by Section 953(b) of the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 and Item 402(u) of Regulation S-K, TVA is providing the following information regarding the annual total compensation of TVA's CEO position and the annual total compensation of the median employee of the company:

• | The total compensation for the CEO position for 2019 was $15,099,142. This amount equals the total compensation for Mr. Johnson (former CEO) and Mr. Lyash (current CEO) as reported in the Summary Compensation table.

• | For 2019, Mr. Johnson's annual total compensation was $6,935,619.

• | For 2019, Mr. Lyash's annual total compensation was $8,163,523.

• | For 2019, the median employee's annual total compensation was $134,749.

Based on this information, the pay ratio of the total compensation for the CEO position to the median employee was approximately 112 to 1.
To identify the median employee and to determine the annual total compensation of the median employee and Mr. Lyash and Mr. Johnson, TVA took the following steps:

• | TVA selected September 30, 2019 as the date on which to identify its median employee. On September 30, 2019, TVA's employee population (including full-time, part-time, and temporary employees) consisted of 11,013 individuals located in the U.S.

• | In order to identify the median employee from its employee population, TVA compared the compensation that would be included in Box 5 (Medicare Wages and Tips) of Form W-2, which includes salary, overtime, and incentive compensation, for the period from October 1, 2018 to September 30, 2019. Box 5 compensation was used as it is representative of the compensation received by all employees and is readily available and objective.

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• | After identifying its median employee, TVA calculated that employee's compensation for 2019 as though that compensation were being calculated for purposes of the Summary Compensation Table, resulting in annual total compensation of $134,749.

The above pay ratio is a reasonable estimate calculated in a manner consistent with Item 402(u) of Regulation S-K. Because Item 402(u) provides companies with flexibility to select the methodology and assumptions used to identify the median employee and to calculate the pay ratio, the pay ratio reported by TVA may not be comparable to the pay ratios reported by other companies.
Director Compensation
The TVA Act provides for up to nine directors on the TVA Board. As of November 14, 2019, the TVA Board consisted of nine members. Under the TVA Act, each director receives certain stipends that are increased annually by the same percentage increase applicable to adjustments under 5 U.S.C. § 5318, which adjusts the annual rates of pay of employees on the Executive Schedule of the U.S. Government. Effective January 6, 2019, the annual stipend for TVA directors was increased to $52,702 per year unless (1) the director chairs a TVA Board committee, in which case the stipend was increased to $53,745 per year, or (2) the director is the Chair of the TVA Board, in which case the stipend was increased to $58,650 per year. Directors are also reimbursed under federal law for travel, lodging, and related expenses while attending meetings and for other official TVA business.
The annual stipends provided by the TVA Act for each director and for the Chair of the TVA Board as of November 14, 2019, are listed below:

TVA Board Annual Stipends
Name | Annual Stipend
James R. Thompson, III |  | $ | 58,650 |
Kenneth E. Allen |  | 52,702 |
A. D. Frazier |  | 52,702 |
Richard B. Howorth |  | 53,745 |
William Kilbride |  | 52,702 |
Virginia T. Lodge |  | 53,745 |
John L. Ryder |  | 53,745 |
Jeff W. Smith |  | 53,745 |
Ronald A. Walter |  | 53,745 |

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The following table provides information on the compensation received by TVA's directors during 2019:

Director Compensation
Name | Fees Earned or Paid in Cash | Stock Awards | Option Awards | Non-Equity Incentive Plan Compensation | Change in Pension Value and Nonqualified Deferred Compensation Earnings(1) | All Other Compensation(2) | Total
James R. Thompson, III | $ | 54,993 |  | — | — | — | — | $ | 546 |  | $ | 55,539 |
Kenneth E. Allen | 52,174 |  | — | — | — | — | 520 |  | 52,694 |
A. D. Frazier | 52,174 |  | — | — | — | — | 2,599 |  | 54,773 |
Richard C. Howorth | 56,277 |  | — | — | — | — | 2,813 |  | 59,090 |
William B. Kilbride | 7,596 |  | — | — | — | — | 74 |  | 7,670 |
Virginia T. Lodge | 53,207 |  | — | — | — | — | 2,650 |  | 55,857 |
John L. Ryder | 28,202 |  | — | — | — | — | 1,118 |  | 29,320 |
Jeff W. Smith | 53,207 |  | — | — | — | — | 2,385 |  | 55,592 |
Ronald A. Walter | 53,207 |  | — | — | — | — | 530 |  | 53,737 |

Notes
(1) TVA directors do not participate in the TVARS Retirement Plans, TVA's SERP, or any non-qualified deferred compensation plan available to TVA employees. However, as appointed officers of the U.S. government, the directors are members of FERS. FERS is administered by the federal Office of Personnel Management, and information regarding the value of FERS pension benefits is not available to TVA.
(2) These amounts include TVA's non-elective and matching contributions to the TSP.
The directors are not eligible to participate in any incentive programs available to TVA employees. The directors do not participate in the TVARS Retirement Plans and do not participate in TVA's SERP. However, as appointed officers of the U.S. government, the directors are members of the Federal Employees Retirement System ("FERS"). FERS is a tiered retirement plan that includes three components: (1) Social Security benefits, (2) the Basic Benefit Plan, and (3) the Thrift Savings Plan ("TSP"). As members of FERS, each director is required to make a mandatory percentage contribution of his or her stipend to the Basic Benefit Plan in the amount of 0.8 percent for those directors appointed prior to January 1, 2013, 3.1 percent for those directors appointed between January 1, 2013, and December 31, 2013, and 4.4 percent for those directors appointed on or after January 1, 2014.
The FERS Basic Benefit Plan is a qualified defined benefit plan that provides a retirement benefit based on a final average pay formula that includes age, highest average salary during any three consecutive years of service, and years of creditable service. A director must have at least five years of creditable service to be eligible to receive retirement benefits. Directors are eligible for immediate, unreduced retirement benefits once (1) they reach age 62 and have five years of FERS creditable service, (2) they reach age 60 and have 20 years of FERS creditable service, or (3) they attain the minimum retirement age and accumulate the specified years of service as set forth in the FERS regulations. Generally, benefits are calculated by multiplying 1.0 percent of the highest average salary during any three consecutive years of service by the number of years of creditable service. Directors who retire at age 62 or later with at least 20 years of FERS creditable service receive an enhanced benefit (a factor of 1.1 percent is used rather than 1.0 percent).
Each director is also eligible to participate in the TSP. The TSP is a tax-deferred retirement savings and investment plan that offers the same type of savings and tax benefits offered under 401(k) plans. Once a director becomes eligible, TVA contributes an amount equal to one percent of the director's stipend into a TSP account for the director. These contributions are made automatically every two weeks regardless of whether the director makes a contribution of his or her own money. Directors are eligible to contribute up to the TSP elective deferral limit. Directors receive matching contributions of 100 percent of each dollar for the first three percent of the director's stipend and 50 percent of each dollar for the next two percent of the director's stipend.
TVA offers a group of health and other benefits (medical, dental, vision, life and accidental death and disability insurance, and long-term disability insurance) that are available to a broad group of employees. Directors are eligible to participate in TVA's health benefit plans and other non-retirement benefit plans on the same terms and at the same contribution rates as other TVA employees.
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Compensation Committee Interlocks and Insider Participation
The People and Performance Committee of the TVA Board currently consists of the following four directors: Virginia T. Lodge, Ronald A. Walter, James R. Thompson, III, and Kenneth Allen.
No executive officer of TVA serves on the board of an entity that has an executive officer serving as a director of TVA.
Compensation Committee Report
The People and Performance Committee has reviewed and discussed the Compensation Discussion and Analysis with management, and based on the review and discussions, the Committee recommended to the TVA Board that the Compensation Discussion and Analysis be included in this Annual Report.
PEOPLE AND PERFORMANCE COMMITTEE
Virginia T. Lodge, Chair
Ronald A. Walter
James R. Thompson, III
Kenneth Allen, Chair-Elect
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
Not applicable.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Director Independence
The composition of the TVA Board is governed by the TVA Act. The TVA Act contains certain provisions that are similar to the considerations for independence under section 10A(m)(3) of the Exchange Act, including that to be eligible for appointment to the TVA Board, an individual shall not be an employee of TVA and shall make full disclosure to Congress of any investment or other financial interest that the individual holds in the energy industry.
Related Party Transactions
Conflict of Interest Provisions
All TVA employees, including directors and executive officers, are subject to the conflict of interest laws and regulations applicable to employees of the federal government. Accordingly, the general federal conflict of interest statute (18 U.S.C. § 208) and the Standards of Ethical Conduct for Employees of the Executive Branch (5 C.F.R. part 2635) ("Standards of Ethical Conduct") form the basis of TVA's policies and procedures for the review, approval, or ratification of related party transactions. The general federal conflict of interest statute, subject to certain exceptions, prohibits each government employee, including TVA's directors and executive officers, from participating personally and substantially (by advice, decision, or otherwise) as a government employee in any contract, controversy, proceeding, request for determination, or other particular matter in which, to his or her knowledge, he or she (or his or her spouse, minor child, general partner, organization with which he or she serves as officer, director, employee, trustee, or general partner, or any person or organization with which he or she is negotiating, or has an arrangement, for future employment) has a financial interest. Exceptions to the statutory prohibition relevant to TVA employees are (1) financial interests which have been deemed by the U.S. Office of Government Ethics, in published regulations, to be too remote or inconsequential to affect the integrity of the employee's services, or (2) interests which are determined in writing, after full disclosure and on a case-by-case basis, to be not so substantial as to be deemed likely to affect the integrity of the employee's services for TVA. In accordance with the statute, individual waiver determinations are made by the official responsible for the employee's appointment. In the case of TVA directors, the determination may be made by the Chair of the TVA Board, and in the case of the Chair of the TVA Board, the determination may be made by the Counsel to the President of the U.S.
More broadly, Subpart E of the Standards of Ethical Conduct provides that where an employee (1) knows that a particular matter involving specific parties is likely to have a direct and predictable effect on the financial interests of a member of his or her household, or that a person with whom the employee has a "covered relationship" (which includes, but is not limited to, persons with whom the employee has a close family relationship and organizations in which the employee is an active participant) is or represents a party to the matter, and (2) determines that the circumstances would cause a reasonable person with knowledge of relevant facts to question his or her impartiality in the matter, the employee should not participate in the matter absent agency authorization. This authorization may be given by the employee's supervising officer, as agency designee, in consultation with the TVA Designated Agency Ethics Official, upon the determination that TVA's interest in the employee's
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participation in the matter outweighs the concern that a reasonable person may question the integrity of TVA's programs and operations.
The previously described restrictions are reflected in TVA's policies which require employees, including directors and executive officers, to comply with the guidelines outlined in the Standards of Ethical Conduct and which restate the standard of the conflict of interest statute.
Additionally, the TVA Board approved a written conflict of interest policy that applies to all TVA employees, including TVA's directors and executive officers. The conflict of interest policy reaffirms the requirement that all TVA employees must comply with applicable federal conflict of interest laws, regulations, and policies. It also establishes an additional policy that is applicable to TVA's directors and CEO. This additional policy provides that TVA's directors and CEO shall not hold a financial interest in (1) any distributor of TVA power, (2) any entity engaged primarily in the wholesale or retail generation, transmission, or sale of electricity, except where substantially all such business is conducted outside of North America, or (3) any entity that may reasonably be perceived as likely to be adversely affected by the success of TVA as a producer or transmitter of electric power. Any waiver of this additional policy may be made only by the TVA Board and will be disclosed promptly to the public, subject to the limitations on disclosure imposed by law.
TVA also has a protocol titled the "Obtaining Things of Value from TVA Protocol" (the "Protocol"). The Protocol describes what a TVA employee should do if a person covered by the Protocol asks for assistance in obtaining a specified thing of value from TVA. Similarly, the TVA Board Practice on External Inquiries describes what a member of the TVA Board should do if a person covered by the practice asks for assistance in obtaining a specified thing of value from TVA.
TVA relies on the policies, practices, laws, and regulations discussed above to regulate conflicts of interest involving employees, including directors and executive officers. TVA has no other written or unwritten policy for the approval or ratification of any transactions in which TVA was or is to be a participant and in which any director or executive officer of TVA (or any child, stepchild, parent, stepparent, spouse, sibling, mother-in-law, father-in-law, son-in-law, daughter-in-law, brother-in-law, or sister-in-law of any director or executive officer of TVA) had or will have a direct or indirect material interest.
Other Relationships
TVA is engaged in a number of transactions with other agencies of the U.S. government, although such agencies do not fall within the definition of "related parties" for purposes of Item 404(a) of Regulation S-K. These include, among other things, supplying electricity to other federal agencies, purchasing electricity from the Southeastern Power Administration, and engaging in various arrangements involving nuclear materials with the Department of Energy ("DOE"). See Item 1, Business and Note 23 — Related Parties.
TVA also has access to a financing arrangement with the U.S. Treasury. TVA and the U.S. Treasury have a memorandum of understanding under which the U.S. Treasury provides TVA with a $150 million credit facility. There were no outstanding borrowings under the facility at September 30, 2019. This credit facility matures on September 30, 2020, and is expected to be renewed. This arrangement is pursuant to the TVA Act. Access to this credit facility or other similar financing arrangements with the U.S. Treasury has been available to TVA since the 1960s. See Note 13 — Debt and Other Obligations —Credit Facility Agreements.
In addition, TVA is required by the 1959 amendment to the TVA Act to make annual payments to the U.S. Treasury from net power proceeds as a repayment of and as a return on the 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") until $1.0 billion of the Power Program Appropriation Investment has been repaid. With the 2014 payment, TVA fulfilled its requirement to repay $1.0 billion of the Power Program Appropriation Investment. The TVA Act requires TVA to continue to make payments to the U.S. Treasury indefinitely as a return on the remaining $258 million of the Power Program Appropriation Investment. See Note 18 — Proprietary Capital — Appropriation Investment.
The TVA Act requires the proceeds for each fiscal year derived from the sale of power or any other activities to be paid into the U.S. Treasury on March 31 of each year, except for the portion of such proceeds as in the opinion of the TVA Board shall be necessary for TVA in the operation of dams and reservoirs and in conducting its business in generating, transmitting, and distributing electric energy. For each fiscal year, the TVA Board adopts a resolution retaining for use in the operation of the TVA power system the entire margin of net power proceeds remaining at the conclusion of such fiscal year.
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ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
The following table shows the fees of Ernst & Young LLP for audit, audit-related, and other services for the years ended September 30, 2019 and 2018.

Principal Accountant Fees and Services (in actual dollars)
Year |  | Principal Accountant |  | Audit Fees(1) |  | Audit-Related Fees |  | All Other Fees(2) |  | Total
2019 |  | Ernst & Young LLP |  | $ | 2,839,049 |  |  | $ | — |  |  | 7,020 |  |  | $ | 2,846,069 |
2018 |  | Ernst & Young LLP |  | 2,798,575 |  |  | — |  |  | — |  |  | 2,798,575 |

Notes
(1) Audit fees consist of payments for professional services rendered in connection with the audit of TVA's annual financial statements, including the annual attestation on internal control over financial reporting and the review of interim financial statements included in TVA's quarterly reports; audit of TVA's fuel cost adjustment; federal financial reporting responsibilities for the preparation and audit of the 2019 and 2018 federal consolidated financial statements of which TVA is a component; Bond offering and other financing comfort letters; and accounting consultations related to TVA's adoption of the new revenue recognition and lease accounting standards.
(2) All other fees reflect accounting and financial reporting research software license costs.
The TVA Board has an Audit, Risk, and Regulation Committee ("Audit Committee"). Under the TVA Act, the Audit Committee, in consultation with the Inspector General, recommends to the TVA Board the selection of an external auditor. TVA's Audit Committee, in consultation with the Inspector General, recommended that the TVA Board select Ernst & Young LLP as TVA's external auditor for the 2019 and 2018 audits and other related services, and the TVA Board approved these recommendations.
TVA has a policy (the "Policy") that requires all auditing services and permissible non-audit services provided by the external auditor to be pre-approved by the Audit Committee. The Policy also lists the following services as ones the external auditor is not permitted to perform:

• | Bookkeeping or other services related to the accounting records or financial statements of TVA;

• | Financial information system design and implementation;

• | Appraisal or valuation services, fairness opinions, and contribution-in-kind reports;

• | Actuarial services;

• | Internal audit outsourcing services;

• | Management functions or human resources;

• | Broker or dealer, investment adviser, or investment banking services;

• | Legal services and expert services unrelated to the audit; and

• | Any other services that the Public Company Accounting Oversight Board determines, by regulation, are impermissible.

The Policy also delegates to the Chair of the Audit Committee the authority to pre-approve a permissible service so long as the amount of the service does not exceed $100,000 and the total amount of services pre-approved during the year by the Chair does not exceed $200,000. The Chair must report for informational purposes the services pre-approved under this provision at the Audit Committee's next meeting.
The Audit Committee pre-approved all audit services for 2019 and 2018.
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PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
(a) The following documents have been filed as part of this Annual Report:

(1) | Consolidated Financial Statements. The following documents are provided in Item 8, Financial Statements and

Supplementary Data herein:
Consolidated Statements of Operations
Consolidated Statements of Comprehensive Income (Loss)
Consolidated Balance Sheets
Consolidated Statements of Cash Flows
Consolidated Statements of Changes in Proprietary Capital
Notes to Consolidated Financial Statements
Report of Independent Registered Public Accounting Firm (Ernst & Young LLP)
(2) Consolidated Financial Statement Schedules.
Schedules not included are omitted because they are not required or because the required information is provided in the consolidated financial statements, including the notes thereto.
(3) List of Exhibits

Exhibit No. | Description
3.1 | Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (Incorporated by reference to Exhibit 3.1 to TVA's Quarterly Report on Form 10-Q for the quarter ended December 31, 2016, File No. 000-52313)
3.2 | Bylaws of the Tennessee Valley Authority Adopted by the TVA Board of Directors on May 18, 2006, as amended on April 3, 2008, May 19, 2008, June 10, 2010, February 13, 2014, August 21, 2014, and November 6, 2014 (Incorporated by reference to Exhibit 3.2 to TVA's Annual Report on Form 10-K for the year ended September 30, 2014, File No. 000-52313)
4.1 | Basic Tennessee Valley Authority Power Bond Resolution Adopted by the TVA Board of Directors on October 6, 1960, as Amended on September 28, 1976, October 17, 1989, and March 25, 1992 (Incorporated by reference to Exhibit 4.1 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.1 | Amended and Restated September Maturity Credit Agreement Dated as of September 28, 2018, Among Tennessee Valley Authority, as the Borrower, Toronto Dominion (Texas) LLC, as Administrative Agent, The Toronto-Dominion Bank, New York Branch, as Letter of Credit Issuer and a Lender, Canadian Imperial Bank of Commerce, New York Branch, First Tennessee Bank National Association, Morgan Stanley Bank, N.A., and The Bank of New York Mellon (Incorporated by Reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on October 3, 2018, File No. 000-52313)
10.2 | Amended and Restated June Maturity Credit Agreement Dated as of June 13, 2018, Among Tennessee Valley Authority, as the Borrower, Royal Bank of Canada, as Administrative Agent, Letter of Credit Issuer, and a Lender, Barclays Bank PLC, BNP Paribas, Branch Banking and Trust Company, Mizuho Bank Ltd, Regions Bank, SunTrust Bank, and Wells Fargo Bank, National Association (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on June 18, 2018, File No. 000-52313)
10.3 | $500,000,000 February Maturity Credit Agreement Dated as of August 7, 2015, Among TVA, Bank of America, N.A., as Administrative Agent, Letter of Credit Issuer, and a Lender, and the Other Lenders Party Thereto (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on August 7, 2015, File No. 000-52313)
10.4 | First Amendment Dated as of February 28, 2017, to the $500,000,000 February Maturity Credit Agreement Dated as of August 7, 2015, Among TVA, Bank of America, N.A., as Administrative Agent, Letter of Credit Issuer, and a Lender, and the Other Lenders Party Thereto (Incorporated by Reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on March 3, 2017, File No. 000-52313)
10.5 | Second Amendment Dated as of February 21, 2018, to the $500,000,000 February Maturity Credit Agreement Dated as of August 7, 2015, and Amended as of February 28, 2017, among TVA, Bank of America, N.A., as Administrative Agent, Letter of Credit Issuer, and a Lender, and the Other Lenders Party Thereto (Incorporated by Reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on February 26, 2018, File No. 000-52313)

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10.6 | December 2019 Maturity Community Bank Credit Agreement Dated as of December 12, 2016, with SunTrust Bank as Administrative Agent and a Lender, Branch Banking and Trust Company as Letter of Credit Issuer and a Lender, First National Bank, First Tennessee Bank National Association, HomeTrust Bank, Pinnacle Bank, Regions Bank, Trustmark National Bank, and United Community Bank (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on December 15, 2016, File No. 000-52313)
10.7 | Amendment Dated as of December 11, 2018, to December Maturity Community Bank Credit Agreement Dated as of December 12, 2016 (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on December 14, 2018, File No. 000-52313)
10.8 | TVA Discount Notes Selling Group Agreement (Incorporated by reference to Exhibit 10.2 to TVA's Quarterly Report on Form 10-Q for the quarter ended June 30, 2008, File No. 000-52313)
10.9 | Electronotes® Selling Agent Agreement Dated as of June 1, 2006, Among TVA, LaSalle Financial Services, Inc., A.G. Edwards & Sons, Inc., Citigroup Global Markets Inc., Edward D. Jones & Co., L.P., First Tennessee Bank National Association, J.J.B. Hilliard, W.L. Lyons, Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Morgan Stanley & Co. Incorporated, and Wachovia Securities, LLC (Incorporated by reference to Exhibit 10.4 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.10 | Amendment Dated as of December 4, 2013, to Electronotes® Selling Agent Agreement Dated as of June 1, 2006, Among TVA, LaSalle Financial Services, Inc., A.G. Edwards & Sons, Inc., Citigroup Global Markets Inc., Edward D. Jones & Co., L.P., First Tennessee Bank National Association, J.J.B. Hilliard, W.L. Lyons, Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Morgan Stanley & Co. Incorporated, and Wachovia Securities, LLC (Incorporated by reference to Exhibit 10.3 to TVA's Quarterly Report on Form 10-Q for the quarter ended March 31, 2014, File No. 000-52313)
10.11 | Second Amendment Dated as of August 28, 2015, to Electronotes® Selling Agent Agreement Dated as of June 1, 2006, and Amended as of December 4, 2013, Among TVA, LaSalle Financial Services, Inc., A.G. Edwards & Sons, Inc., Citigroup Global Markets Inc., Edward D. Jones & Co., L.P., First Tennessee Bank National Association, J.J.B. Hilliard, W.L. Lyons, Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Morgan Stanley & Co. Incorporated, and Wachovia Securities, LLC (Incorporated by reference to Exhibit 10.9 to TVA's Annual Report on Form 10-K for the year ended September 30, 2015, File No. 000-52313)
10.12 | Assumption Agreement Between TVA and Incapital LLC Dated as of February 29, 2008, Relating to the Electronotes® Selling Agent Agreement Dated as of June 1, 2006, Among TVA, LaSalle Financial Services, Inc., A.G. Edwards & Sons, Inc., Citigroup Global Markets Inc., Edward D. Jones & Co., L.P., First Tennessee Bank National Association, J.J.B. Hilliard, W.L. Lyons, Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Morgan Stanley & Co. Incorporated, and Wachovia Securities, LLC (Incorporated by reference to Exhibit 10.1 to TVA's Quarterly Report on Form 10-Q for the quarter ended March 31, 2008, File No. 000-52313)
10.13 | Commitment Agreement Among Memphis Light, Gas and Water Division, the City of Memphis, Tennessee, and TVA Dated as of November 19, 2003 (Incorporated by reference to Exhibit 10.5 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.14 | Power Contract Supplement No. 95 Among Memphis Light, Gas and Water Division, the City of Memphis, Tennessee, and TVA Dated as of November 19, 2003 (Incorporated by reference to Exhibit 10.6 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.15 | Void Walk Away Agreement Among Memphis Light, Gas and Water Division, the City of Memphis, Tennessee, and TVA Dated as of November 20, 2003 (Incorporated by reference to Exhibit 10.7 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.16 | Power Contract Supplement No. 96 Among Memphis Light, Gas and Water Division, the City of Memphis, Tennessee, and TVA Dated as of November 20, 2003 (Incorporated by reference to Exhibit 10.8 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.17 | Overview of TVA's September 26, 2003, Lease and Leaseback of Control, Monitoring, and Data Analysis Network with Respect to TVA's Transmission System in Tennessee, Kentucky, Georgia, and Mississippi (Incorporated by reference to Exhibit 10.9 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.18 | Participation Agreement Dated as of September 22, 2003, Among (1) TVA, (2) NVG Network I Statutory Trust, (3) Wells Fargo Delaware Trust Company, Not in Its Individual Capacity, Except to the Extent Expressly Provided in the Participation Agreement, But as Owner Trustee, (4) Wachovia Mortgage Corporation, (5) Wilmington Trust Company, Not in Its Individual Capacity, Except to the Extent Expressly Provided in the Participation Agreement, But as Lease Indenture Trustee, and (6) Wilmington Trust Company, Not in Its Individual Capacity, Except to the Extent Expressly Provided in the Participation Agreement, But as Pass Through Trustee (Incorporated by reference to Exhibit 10.10 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.19* | Network Lease Agreement Dated as of September 26, 2003, Between NVG Network I Statutory Trust, as Owner Lessor, and TVA, as Lessee (Incorporated by reference to Exhibit 10.11 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)

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10.20* | Head Lease Agreement Dated as of September 26, 2003, Between TVA, as Head Lessor, and NVG Network I Statutory Trust, as Head Lessee (Incorporated by reference to Exhibit 10.12 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.21* | Leasehold Security Agreement Dated as of September 26, 2003, Made by NVG Network I Statutory Trust to TVA (Incorporated by reference to Exhibit 10.13 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
10.22 | Facility Lease-Purchase Agreement Dated as of January 17, 2012, Between John Sevier Combined Cycle Generation LLC and TVA (Incorporated by reference to Exhibit 10.1 to TVA's Quarterly Report on Form 10-Q for the quarter ended December 31, 2011, File No. 000-52313)
10.23 | Head Lease Agreement Dated as of January 17, 2012, Among the United States of America, TVA, and John Sevier Combined Cycle Generation LLC (Incorporated by reference to Exhibit 10.2 to TVA's Quarterly Report on Form 10-Q for the quarter ended December 31, 2011, File No. 000-52313)
10.24* | Asset Purchase Agreement Dated as of August 6, 2013, Between TVA and Seven States Southaven, LLC (Incorporated by reference to Exhibit 10.33 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)
10.25 | Facility Lease-Purchase Agreement Dated as of August 9, 2013, Between Southaven Combined Cycle Generation LLC and TVA (Incorporated by reference to Exhibit 10.34 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)
10.26 | Head Lease Agreement Dated as of August 9, 2013, Among the United States of America, TVA, and Southaven Combined Cycle Generation LLC (Incorporated by reference to Exhibit 10.35 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)
10.27* | Federal Facilities Compliance Agreement Between the United States Environmental Protection Agency and TVA (Incorporated by reference to Exhibit 10.2 to TVA's Quarterly Report on Form 10-Q for the quarter ended June 30, 2011, File No. 000-52313)
10.28* | Consent Decree Among Alabama, Kentucky, North Carolina, Tennessee, the Alabama Department of Environmental Management, the National Parks Conservation Association, Inc., the Sierra Club, Our Children's Earth Foundation, and TVA (Incorporated by reference to Exhibit 10.3 to TVA's Quarterly Report on Form 10-Q for the quarter ended June 30, 2011, File No. 000-52313)
10.29† | Amended and Restated TVA Compensation Plan Approved by the TVA Board on August 22, 2019 (Incorporated by Reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on August 28, 2019, File No. 000-52313)
10.30† | Amended and Restated Supplemental Executive Retirement Plan Effective as of May 1, 2015 (Incorporated by reference to Exhibit 10.1 to TVA's Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, File No. 000-52313)
10.31† | Amended and Restated Executive Annual Incentive Plan Effective as of October 1, 2015 (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on October 1, 2015, File No. 000-52313)
10.32† | Deferred Compensation Plan (Incorporated by reference to Exhibit 10.2 to TVA's Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.33† | Amended and Restated Long-Term Incentive Plan Dated as of August 22, 2018 (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on August 22, 2018, File No. 000-52313)
10.34† | Retention Incentive Plan Effective as of October 1, 2015 (Incorporated by reference to Exhibit 10.2 to TVA's Current Report on Form 8-K filed on October 1, 2015, File No. 000-52313)
10.35† | Offer Letter to William D. Johnson Approved as of November 1, 2012 (Incorporated by reference to Exhibit 99.1 to TVA's Current Report on Form 8-K filed on November 7, 2012, File No. 000-52313)
10.36 | Offer Letter to Jeffrey J. Lyash Approved as of February 14, 2019 (Incorporated by reference to Exhibit 10.1 TVA's Current Report on Form 8-K filed on February 14, 2019, File No. 000-52313)
10.37 | Acknowledgment by TVA and Jeffrey J. Lyash on March 25, 2019, Relating to the Offer Letter to Mr. Lyash Approved as of February 14, 2019 (Incorporated by reference to Exhibit 10.2 to TVA's Quarterly Report on Form 10-Q for the quarter ended March 31, 2019, File No. 000-52313)

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10.38† | Offer Letter to Sherry A. Quirk Accepted as of December 29, 2014 (Incorporated by Reference to Exhibit 10.40 to TVA's Annual Report on Form 10-K for the year ended September 30, 2017, File No. 000-52313)
10.39† | Offer Letter to Timothy S. Rausch Accepted as of September 18, 2018
10.40† | Deferral Agreement Between TVA and Michael D. Skaggs Dated as of March 20, 2013 (Incorporated by reference to Exhibit 10.62 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)
14.1 | Disclosure and Financial Ethics Code (Incorporated by reference to Exhibit 14 to TVA's Annual Report on Form 10-K for the year ended September 30, 2006, File No. 000-52313)
14.2 | TVA Conflict of Interest Policy, as amended (Incorporated by reference to Exhibit 14.2 to TVA's Annual Report on Form 10-K for the year ended September 30, 2014, File No. 000-52313)
31.1 | Rule 13a-14(a)/15d-14(a) Certification Executed by the Chief Executive Officer
31.2 | Rule 13a-14(a)/15d-14(a) Certification Executed by the Chief Financial Officer
32.1 | Section 1350 Certification Executed by the Chief Executive Officer
32.2 | Section 1350 Certification Executed by the Chief Financial Officer
101.INS | TVA XBRL Instance Document
101.SCH | TVA XBRL Taxonomy Extension Schema
101.CAL | TVA XBRL Taxonomy Extension Calculation Linkbase
101.DEF | TVA XBRL Taxonomy Extension Definition Linkbase
101.LAB | TVA XBRL Taxonomy Extension Label Linkbase
101.PRE | TVA XBRL Taxonomy Extension Presentation Linkbase
† Management contract or compensatory arrangement. * Certain schedule(s) and/or exhibit(s) have been omitted. TVA hereby undertakes to furnish supplementally copies of any of the omitted schedules and/or exhibits upon request by the Securities and Exchange Commission.

ITEM 16. FORM 10-K SUMMARY
Not applicable.
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SIGNATURES
Pursuant to the requirements of Section 13, 15(d), or 37 of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: | November 14, 2019 |  | TENNESSEE VALLEY AUTHORITY
|  |  | (Registrant)
|  | By: | /s/ Jeffrey J. Lyash
|  |  | Jeffrey J. Lyash
|  |  | President and Chief Executive Officer

SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
192

Signature | Title | Date
/s/ Jeffrey J. Lyash | President and Chief Executive Officer | November 14, 2019
Jeffrey J. Lyash | (Principal Executive Officer) |
/s/ John M. Thomas, III | Executive Vice President and | November 14, 2019
John M. Thomas, III | Chief Financial Officer |
| (Principal Financial Officer) |
/s/ Diane Wear | Vice President and Controller | November 14, 2019
Diane Wear | (Principal Accounting Officer) |
| Chair | November 14, 2019
James R. Thompson, III |  |
| Director | November 14, 2019
Kenneth E. Allen |  |
| Director | November 14, 2019
A. D. Frazier |  |
| Director | November 14, 2019
Richard C. Howorth |  |
| Director | November 14, 2019
William Kilbride |  |
| Director | November 14, 2019
Virginia T. Lodge |  |
| Director | November 14, 2019
John Ryder |  |
| Director | November 14, 2019
Jeff W. Smith |  |
| Director | November 14, 2019
Ronald A. Walter |  |

193