10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(MARK ONE)

x ANNUAL REPORT PURSUANT TO

13, 15(d), OR 37 OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended September 30, 2014

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:  None

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, Section 15(d), or Section 37 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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).

Yes x  No o

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. x

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer o                                                Accelerated filer o

Non-accelerated filer   x                                               Smaller reporting company  o

(Do not check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the 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.......................................................................................................................................................................................................................................	8
Customers..........................................................................................................................................................................................................................................	10
Rates..................................................................................................................................................................................................................................................	11
Power Supply......................................................................................................................................................................................................................................	12
Cleaner Energy Initiatives..................................................................................................................................................................................................................	20
Fuel Supply.........................................................................................................................................................................................................................................	21
Transmission......................................................................................................................................................................................................................................	24
Weather and Seasonality....................................................................................................................................................................................................................	25
Competition........................................................................................................................................................................................................................................	25
Research and Development...............................................................................................................................................................................................................	25
Flood Control Activities.......................................................................................................................................................................................................................	26
Environmental Stewardship Activities.................................................................................................................................................................................................	26
Economic Development Activities......................................................................................................................................................................................................	26
Regulation..........................................................................................................................................................................................................................................	27
Taxation and Tax Equivalents.............................................................................................................................................................................................................	28
Environmental Matters.......................................................................................................................................................................................................................	28
Employees..........................................................................................................................................................................................................................................	33
ITEM 1A. RISK FACTORS............................................................................................................................................................................................................................	34
ITEM 1B. UNRESOLVED STAFF COMMENTS............................................................................................................................................................................................	44
ITEM 2. PROPERTIES..................................................................................................................................................................................................................................	44
Generating Properties........................................................................................................................................................................................................................	44
Transmission Properties.....................................................................................................................................................................................................................	44
Natural Resource Stewardship Properties.........................................................................................................................................................................................	44
Buildings.............................................................................................................................................................................................................................................	45
Disposal of Property...........................................................................................................................................................................................................................	45
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........................................................................................................................................................................................................	47
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS...................................................................	48
Overview.............................................................................................................................................................................................................................................	48
Business and Mission.........................................................................................................................................................................................................................	48
Executive Overview............................................................................................................................................................................................................................	50
Results of Operations.........................................................................................................................................................................................................................	50
Liquidity and Capital Resources.........................................................................................................................................................................................................	55
Off-Balance Sheet Arrangements.......................................................................................................................................................................................................	62
Key Initiatives and Challenges...........................................................................................................................................................................................................	62
Critical Accounting Policies and Estimates.........................................................................................................................................................................................	67
Fair Value Measurements...................................................................................................................................................................................................................	74
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...........................................................................................................................	81
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA..........................................................................................................................................................	82
Consolidated Balance Sheets............................................................................................................................................................................................................	82
Consolidated Statements of Operations.............................................................................................................................................................................................	84

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Consolidated Statements of Comprehensive Income (Loss).............................................................................................................................................................	84
Consolidated Statements of Cash Flows...........................................................................................................................................................................................	85
Consolidated Statements of Changes in Proprietary Capital.............................................................................................................................................................	86
Notes to Consolidated Financial Statements.....................................................................................................................................................................................	87
Report of Independent Registered Public Accounting Firm................................................................................................................................................................	146
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE................................................................	147
ITEM 9A. CONTROLS AND PROCEDURES...............................................................................................................................................................................................	147
Disclosure Controls and Procedures..................................................................................................................................................................................................	147
Internal Control over Financial Reporting...........................................................................................................................................................................................	147
Report of Independent Registered Public Accounting Firm................................................................................................................................................................	148
ITEM 9B. OTHER INFORMATION................................................................................................................................................................................................................	149
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE.............................................................................................................................	150
Directors..............................................................................................................................................................................................................................................	150
Executive Officers...............................................................................................................................................................................................................................	152
Disclosure and Financial Code of Ethics.............................................................................................................................................................................................	153
Committees of the TVA Board.............................................................................................................................................................................................................	153
ITEM 11. EXECUTIVE COMPENSATION.....................................................................................................................................................................................................	154
Compensation Discussion and Analysis..............................................................................................................................................................................................	154
Executive Compensation Tables and Narrative Disclosures...............................................................................................................................................................	171
Retirement and Pension Plans............................................................................................................................................................................................................	175
Potential Payments on Account of Retirement/Resignation, Termination without Cause, Termination with Cause, or Death/Disability.............................................	178
Other Agreements...............................................................................................................................................................................................................................	180
Director Compensation........................................................................................................................................................................................................................	180
Compensation Committee Interlocks and Insider Participation...........................................................................................................................................................	182
Compensation Committee Report.......................................................................................................................................................................................................	182
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS......................................	182
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.........................................................................................	182
Director Independence........................................................................................................................................................................................................................	182
Related Party Transactions.................................................................................................................................................................................................................	182
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES......................................................................................................................................................................	184
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES.....................................................................................................................................................................	186
SIGNATURES................................................................................................................................................................................................................................................	191
EXHIBIT INDEX.............................................................................................................................................................................................................................................	193

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GLOSSARY OF COMMON ACRONYMS
Following are definitions of terms or acronyms frequently used in this Annual Report on Form 10-K for the fiscal year ended September 30, 2014 (the “Annual Report”):
Term or Acronym	Definition
AFUDC	Allowance for funds used during construction
ARO	Asset retirement obligation
ART	Asset Retirement Trust
ASLB	Atomic Safety and Licensing Board
BEST	Bellefonte Efficiency and Sustainability Team
BREDL	Blue Ridge Environmental Defense League
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
CCOLA	Combined construction and operating license application
CCP	Coal combustion products
CCR	Coal combustion residual
CCW	Coal combustion waste
CERCLA	Comprehensive Environmental Response, Compensation, and Liability Act
CME	Chicago Mercantile Exchange
CO2	Carbon dioxide
CO2e	Carbon dioxide equivalent
COLA	Cost of living adjustment
CSAPR	Cross State Air Pollution Rule
CTs	Combustion turbine unit(s)
CVA	Credit valuation adjustment
CY	Calendar year
DER	Distributed energy resources
EPA	Environmental Protection Agency
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
GAO	U.S. Government Accountability Office
GHG	Greenhouse gas
GWh	Gigawatt hour(s)
IRP	Integrated Resource Plan
IRUs	Indefeasible rights of use
JSCCG	John Sevier Combined Cycle Generation LLC
kWh	Kilowatt hour(s)
LIBOR	London Interbank Offered Rate
LPC	Local power company customer of TVA
MD&A	Management’s Discussion and Analysis of Financial Condition and Results of Operations
mmBtu	Million British thermal unit(s)
MtM	Mark-to-market
MW	Megawatt
NAAQS	National Ambient Air Quality Standards
NAV	Net asset value
NDT	Nuclear Decommissioning Trust
NEIL	Nuclear Electric Insurance Limited

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NEPA	National Environmental Policy Act
NERC	North American Electric Reliability Corporation
NOx	Nitrogen oxides
NPDES	National Pollutant Discharge Elimination System
NRC	Nuclear Regulatory Commission
NRP	Natural Resource Plan
NSPS	New Source Performance Standards
NSR	New Source Review
OCI	Other comprehensive income (loss)
PARRS	Putable Automatic Rate Reset Securities
PM	Particulate matter
PSD	Prevention of Significant Deterioration
QTE	Qualified technological equipment and software
SACE	Southern Alliance for Clean Energy
SCCG	Southaven Combined Cycle Generation, LLC
SCRs	Selective catalytic reduction systems
SEC	Securities and Exchange Commission
SERP	Supplemental Executive Retirement Plan
Seven States	Seven States Power Corporation
SMR	Small modular reactor(s)
SO2	Sulfur dioxide
SSSL	Seven States Southaven, LLC
TCWN	Tennessee Clean Water Network
TDEC	Tennessee Department of Environment & Conservation
TOU	Time-of-use
TVARS	Tennessee Valley Authority Retirement System
TWQCB	Tennessee Water Quality Control Board
USEC	United States Enrichment Corporation
VIE	Variable interest entity
XBRL	eXtensible Business Reporting Language
WCD	Waste Confidence Decision

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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 the 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 the forward-looking statements.  These factors include, among other things:

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

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

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

• Costs and liabilities that are not anticipated in TVA’s financial statements for third-party claims, natural resource damages, or fines or penalties associated with events such as the Kingston Fossil Plant ("Kingston") ash spill as well as for environmental clean-up activities;

• Addition or loss of customers;

• Significant changes in demand for electricity which may result from, among other things, economic downturns, increased energy efficiency and conservation, and improvements in distributed generation and other alternative generation technologies;

• Significant delays, cost increases, or cost overruns associated with the construction of generation or transmission assets;

• Changes in the timing or amount of pension and health care costs;

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

• Physical or cyber attacks on TVA's assets;

• The outcome of legal and administrative proceedings;

• The failure of TVA's generation, transmission, flood control, and related assets, including coal combustion residual ("CCR") facilities, to operate as anticipated, resulting in lost revenues, damages, and 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, droughts, floods, hurricanes, tornadoes, pandemics, wars, national emergencies, terrorist activities, and 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, 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;

• TVA's organizational transformation efforts or cost reduction efforts not being fully successful;

• Inability to obtain, or loss of, regulatory approval for the construction or operation of assets, including Watts Bar Unit 2;

• The requirement or decision to make additional contributions to TVA's pension or other post-retirement benefit plans or to TVA's Nuclear Decommissioning Trust ("NDT") or Asset Retirement Trust ("ART");

• 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, as amended;

• An increase in TVA's cost of capital which 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, and an increased reliance by TVA on alternative financing arrangements as TVA approaches its debt ceiling;

• Changes in the economy and volatility in financial markets;

• Changes in technology;

• Reliability and creditworthiness of counterparties;

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

6

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

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

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

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

• Inability to attract or retain a skilled workforce;

• 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, and 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, negatively affect the cost and schedule for completing Watts Bar Nuclear Plant ("Watts Bar") Unit 2 and preserving Bellefonte Nuclear Plant ("Bellefonte") Unit 1 for possible completion, or cause TVA to forego future construction at these or other facilities;

• Loss of quorum of the TVA Board of Directors; and

• 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 (2014, 2013, 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.  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 purpose of the Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (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 which has been entrusted to TVA as its agent.

Available Information

TVA's Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and all amendments to those reports are available on TVA's web site, free of charge, as soon as reasonably practicable after such material is electronically filed with or furnished to the Securities and Exchange Commission ("SEC").  TVA's web site is www.tva.gov.  Information contained on TVA’s web site shall not be deemed to be incorporated into, or to be a part of, this Annual Report.  TVA's SEC reports are also available to the public without charge from the web site maintained by the SEC at www.sec.gov. 

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PART I

ITEM 1.  BUSINESS

The Corporation

The Tennessee Valley Authority ("TVA") is a corporate agency and instrumentality of the United States ("U.S.") that was created in 1933 by legislation enacted by the U.S. Congress 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 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 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 over nine million people.  In 2014, the revenues generated from TVA’s electricity sales were $11.0 billion and accounted for virtually all of TVA’s revenues.

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.  Consistent with these primary purposes, 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 which have jurisdiction and authority over certain aspects of the river system.  In addition, the TVA Board of Directors (the "TVA Board") established two councils — the Regional Resource Stewardship Council and the Regional Energy Resource Council — under the Federal Advisory Committee Act 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 debt securities 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.

Service Area

The area in which TVA sells power, its service area, is defined by the TVA Act.  Under the TVA Act, subject to certain minor exceptions, TVA may not, without specific authorization from the U.S. Congress, enter into contracts that would have the effect of making it, or the local power company customers of TVA ("LPCs") which distribute TVA power, 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.

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 customers.

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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)
	2014		2013		2012
Alabama	$	1,611	$	1,551	$	1,556
Georgia	268		260		234
Kentucky	680		1,019		1,230
Mississippi	1,056		1,029		1,038
North Carolina	58		52		69
Tennessee	7,246		6,818		6,889
Virginia	51		53		49
Subtotal	10,970		10,782		11,065
Sale for resale and other	29		47		21
Subtotal	10,999		10,829		11,086
Other revenues	138		127		134
Operating revenues	$	11,137	$	10,956	$	11,220

Note

See Power Supply— Coal-Fired for a discussion of idled coal-fired units.

9

Customers

TVA is primarily a wholesaler of power.  It sells power to LPCs which 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 its members.  TVA also sells power to directly served customers, consisting primarily of federal agencies and customers with large or unusual loads.  In addition, power in excess of the needs of the TVA system may, where consistent with the provisions of the TVA Act, be sold under exchange power arrangements with other electric systems.

Operating Revenues by Customer Type For the years ended September 30 (in millions)
	2014		2013		2012
Revenue from sales of electricity
Local power companies	$	10,062	$	9,463	$	9,506
Industries directly served	780		1,199		1,442
Federal agencies and other	157		167		138
Total sales of electricity	10,999		10,829		11,086
Other revenues	138		127		134
Operating revenues	$	11,137	$	10,956	$	11,220

Local Power Company Customers

Revenues from LPCs accounted for 90 percent of TVA’s total operating revenues in 2014.  At September 30, 2014, TVA had wholesale power contracts with 155 LPCs.  Each of these contracts requires the LPCs to purchase from TVA all of its electric power and energy consumed within the TVA service area. All LPCs purchase power under contracts that require five, ten, twelve, or fifteen years notice to terminate.

The number of LPCs with the contract arrangements described above, the revenues derived from such arrangements in 2014, and the percentage of TVA’s 2014 total operating revenues represented by these revenues are summarized in the table below.

TVA Local Power Company Customer Contracts At September 30, 2014
Contract Arrangements(1)	Number of LPCs	Sales to LPCs in 2014		Percentage of Total Operating Revenues in 2014
		(in millions)
15-year termination notice	6	$	159	1.4	%
12-year termination notice	1	$	25	0.2	%
10-year termination notice	48	3,376		30.3	%
5-year termination notice	100	6,502		58.4	%
Total	155	$	10,062	90.3	%

Note

(1)  Ordinarily the LPCs and TVA have the same termination notice period; however, in contracts with five 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.  Also, under TVA’s contract with Bristol Virginia Utilities, a five-year termination notice may not be given by the LPC until January 2018.

TVA’s two largest LPCs — Memphis Light, Gas and Water Division ("MLGW") and Nashville Electric Service ("NES") — have contracts with five-year and 10-year termination notice periods, respectively.  Although no single customer accounted for 10 percent or more of TVA’s total operating revenues in 2014, sales to MLGW and NES accounted for nine percent and eight percent, respectively.

The power contracts between TVA and LPCs provide for purchase of power by LPCs at the wholesale rates established by the TVA Board.  Under Section 10 of 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 specific resale rates and

10

charges at which the LPC must resell TVA power to their 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.  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 an adequate supply of power at the lowest feasible rates. See Rates — Rate Methodology below.

TVA also regulates LPC policies for deposits, termination, information to consumers, and billing through service practice standards that were adopted in 1979. On November 6, 2014, the TVA Board approved a revised service practice policy framework.  The new framework  provides for enhanced, consistent regulatory policy for ratepayers across the Tennessee Valley, while both upholding the intent of the original standards and recognizing local considerations.

Other Customers

Revenues from directly served industrial customers accounted for seven percent of TVA’s total operating revenues in 2014.  Contracts with these customers are subject to termination by the customer or TVA upon a minimum notice period that varies according to the customer’s contract demand and the period of time service has been provided.

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 which 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 ("Bonds") in advance of maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected with TVA’s power business.

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.

Rate Methodology

In view of demand for electricity, the level of competition, and other relevant factors, it is reasonable to assume that rates, set at levels that will recover TVA's costs, can be charged and collected from customers. Further, the TVA Board has the discretion to determine when costs will be recovered in rates. As a result of these factors, TVA records certain assets and liabilities that result from the self-regulated ratemaking process that could not otherwise be so recorded under accounting principles generally accepted in the United States. See Note 1 — Cost-Based Regulation and Note 8.

In setting rates to cover the costs set out in the TVA Act, TVA uses a wholesale rate structure that is comprised of a base rate and a fuel rate that is automatically determined by the operation of the fuel cost adjustment formula each month. 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 capital, such as TVA.

TVA's revenue requirements for costs or projected costs (other than the fuel, purchased power, and related costs covered by the fuel rate) are calculated under the DSC methodology as the sum of the following components:

• Operating and maintenance costs;

• Tax equivalents (other than the amount attributable to fuel cost-related revenues);

• Other costs in accordance with the TVA Act; and

• Debt service coverage.

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This methodology reflects the cause-and-effect relationship between TVA's costs and the corresponding rates it charges for its regulated products and services. Once the revenue requirements (or projected costs) are determined, they are compared to the projected revenues for the year in question, at existing rates, to arrive at the shortfall or surplus of revenues as compared to the projected costs. Power rates are adjusted by the TVA Board to a level deemed to be sufficient to produce revenues approximately equal to projected costs (exclusive of the costs collected through the fuel rate).

TVA's wholesale and retail rate structures include time-of-use ("TOU") and seasonal demand and energy ("SDE") rate structures. These rate structures provide price signals intended to incentivize LPCs and end-use customers to shift energy usage from high-cost generation periods to less expensive generation periods. The rates are intended to more closely align TVA's revenues with its costs.

For LPCs, the default wholesale rate structure is seasonal TOU. The wholesale rate provisions originally specified that the SDE option expired in September 2012. In April 2012, the TVA Board approved optional enhanced TOU and SDE structures which became effective in October 2012. TVA allowed LPCs to elect one of these wholesale rate structures and make retail adjustments consistent with their wholesale elections. LPC elections as of October 1, 2014, were as follows: 148 were served under the enhanced TOU structure, two were served under the default seasonal TOU structure, and five were served under the enhanced SDE structure.

TVA's rates also include a fuel cost recovery mechanism that automatically adjusts its rates each month to recover its fuel costs, which include 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 tax equivalents associated with the fuel cost adjustments.

On August 22, 2013, the TVA Board approved a five-year extension of the environmental adjustment (which commenced in 2004), which reflects the need to collect revenue for environmental expenditures to further TVA's environmental performance, as well as comply with new, more stringent air, water, and waste regulations. The environmental adjustment recovered approximately $437 million in 2014. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Ratemaking. On August 21, 2014, the TVA Board approved a non-fuel base rate increase of 2.61 percent on wholesale rates. It is anticipated this will increase base revenues by approximately $199 million for 2015.

Power Supply

General

Power generating facilities operated by TVA at September 30, 2014, included 29 conventional hydroelectric sites, one pumped-storage hydroelectric site, 10 coal-fired sites, three nuclear sites, 14 natural gas and/or oil-fired sites, one diesel generator site, 16 solar energy sites, digester gas cofiring capacity at one coal-fired site, biomass cofiring potential (located at coal-fired sites), and one wind energy site, although certain of these facilities were out of service as of September 30, 2014. See Net Capability for a discussion of these out-of-service facilities.  TVA also acquires power under power purchase agreements of varying durations as well as short-term contracts of less than 24-hours in duration.

The following table summarizes TVA’s net generation in millions of kilowatt hours ("kWh") by generating source and the percentage of all electric power generated by TVA for the years indicated:

Power Supply from TVA-Operated Generation Facilities For the years ended September 30 (millions of kWh)
	2014				2013				2012
Coal-fired	62,525		44	%	62,519		43	%	58,584	41	%
Nuclear	53,778		38	%	52,100		36	%	55,244	38	%
Hydroelectric	13,228		9	%	18,178		12	%	12,817	9	%
Natural gas and/or oil-fired	12,615		9	%	13,102		9	%	16,650	12	%
Renewable resources (non-hydro)	5	(1)	<1%		9	(1)	<1%		25	<1%
Total	142,151		100	%	145,908		100	%	143,320	100	%

Note

(1)  Operation and maintenance issues reduced the available renewable generation during 2014 and 2013 from several facilities, including those utilizing methane, solar, and wind.

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Net Capability

The following table summarizes TVA's summer net capability in megawatts ("MW") at September 30, 2014:

SUMMER NET CAPABILITY(1) At September 30, 2014
Source of Capability	Location	Number  of Units	Summer Net Capability (MW)	Date First Unit Placed in Service	Date Last Unit Placed in Service
TVA-Operated Generating Facilities
Coal-Fired
Allen(2)	Tennessee	3	741	1959	1959
Bull Run	Tennessee	1	863	1967	1967
Colbert(2),(3)	Alabama	4	712	1955	1965
Cumberland	Tennessee	2	2,470	1973	1973
Gallatin	Tennessee	4	976	1956	1959
Johnsonville	Tennessee	4	428	1951	1959
Kingston	Tennessee	9	1,398	1954	1955
Paradise	Kentucky	3	2,201	1963	1970
Shawnee	Kentucky	9	1,206	1953	1955
Widows Creek(4),(5)	Alabama	2	938	1954	1965
Total Coal-Fired		41	11,933
Nuclear
Browns Ferry	Alabama	3	3,309	1974	1977
Sequoyah	Tennessee	2	2,292	1981	1982
Watts Bar	Tennessee	1	1,123	1996	1996
Total Nuclear		6	6,724
Hydroelectric
Conventional Plants	Alabama	36	1,178	1925	1962
	Georgia	2	33	1931	1956
	Kentucky	5	223	1944	1948
	North Carolina	6	492	1940	1956
	Tennessee	60	1,876	1912	1972
Pumped-Storage(6)	Tennessee	4	1,616	1978	1979
Total Hydroelectric		113	5,418
Natural Gas and/or Oil-Fired(7),(8)
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	600	1975	2000
Gleason(9)	Tennessee	3	465	2000	2000
Johnsonville	Tennessee	20	1,133	1975	2000
Kemper	Mississippi	4	312	2002	2002
Lagoon Creek	Tennessee	12	941	2001	2002
Marshall County	Kentucky	8	621	2002	2002
Subtotal Simple-Cycle Combustion Turbine		87	5,388
Combined-Cycle Combustion Turbine
Caledonia(10)	Mississippi	3	765	2003	2003
John Sevier(11)	Tennessee	1	870	2012	2012
Lagoon Creek(12)	Tennessee	1	525	2010	2010
Magnolia	Mississippi	3	920	2003	2003
Southaven	Mississippi	3	774	2003	2003
Subtotal Combined-Cycle Combustion Turbine		11	3,854
Total Natural Gas and/or Oil-Fired		98	9,242

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Diesel Generator
Meridian	Mississippi	5	9	1998	1998
Total Diesel Generators		5	9
TVA Renewable Resources (non-hydro)(13)			< 1
Total TVA-Operated Generating Facilities			33,326
Contract Renewable Resources(14),(15)			139
Power Purchase and Other Agreements			3,882
Total Summer Net Capability			37,347

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 and

does not include operational limitations such as derates.

(2) Eight MW of cofired methane at Allen and seven MW of cofired biomass at Colbert are accounted for as coal generation as opposed to TVA Renewable

Resources.

(3) Colbert Unit 5 was idled on October 1, 2013.

(4) Widows Creek Units 3 and 5 were retired on July 31, 2013, and Units 1, 2, 4, and 6 were retired on July 31, 2014.

(5) Widows Creek Unit 8 was mothballed on October 1, 2014.

(6) As of September 30, 2014, three of the four Raccoon Mountain Pumped-Storage Plant units were in service. The return to service date for the fourth unit is estimated to be in the third quarter of 2015.

(7) See Item 2, Propertiesfor a discussion of TVA-operated natural gas and/or oil-fired facilities subject to leaseback and long-term lease arrangements.

(8) Peak firing of simple-cycle combustion turbine units accounts for an additional 257 MW of short-term capability.

(9) The units at the Gleason Simple-Cycle Facility were derated to 360 MW as of September 30, 2014, pending maintenance.

(10) Caledonia is currently a leased facility operated by TVA.

(11) John Sevier Combined Cycle Facility is a single steam cycle unit driven by three gas turbines (3x1 configuration).

(12) Lagoon Creek Combined Cycle Facility is a single steam cycle unit driven by two gas turbines (2x1 configuration).

(13) TVA's three wind turbines (2 MW nameplate capacity) at its Buffalo Mountain Site in Tennessee were not operational as of September 30, 2014, and do not appear to be economical for returning to operation. TVA owns 0.4 MW of solar installations at 16 sites.

(14) Contract Renewable Resources include Generation Partners, Renewable Standard Offer, and 15 wind turbine generators located on Buffalo Mountain. See Power Supply — Purchased Power and Other Agreements for information on renewable energy power purchase contracts.

(15) Solar and wind resouces are listed at nameplate capacity.

Coal-Fired

TVA began its coal-fired plant construction program in the 1940s, and its coal-fired units were placed in service between 1951 and 1973. Coal-fired units are either active or inactive. 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.  As of September 30, 2014, TVA had 10 coal-fired plants consisting of 41 active units, accounting for 11,933 MW of summer net capability. As of September 30, 2014, TVA had 18 inactive units. Inactive units may be in three categories: retired, mothballed, or inactive reserve. Retired units are unavailable for service and are not expected to return to service in the future. As of September 30, 2014, TVA had 11 retired units: John Sevier Fossil Plant ("John Sevier") Units 1-4, Shawnee Fossil Plant ("Shawnee") Unit 10, and Widows Creek Fossil Plant ("Widows Creek") Units 1-6. Mothballed units are unavailable for service but can be brought back into service after some maintenance with an appropriate amount of notification, typically weeks or months.  As of September 30, 2014, TVA had seven mothballed units: Johnsonville Fossil Plant ("Johnsonville") Units 5-10 and Colbert Fossil Plant ("Colbert") Unit 5.  Inactive reserve units are unavailable for service but can be brought back into service after some repairs in a relatively short duration of time, typically measured in days. As of September 30, 2014, TVA had no units in inactive reserve. TVA refers to units which are in inactive reserve or mothballed status as idled. In addition, as of October 1, 2014, TVA mothballed Widows Creek Unit 8.

During 2014, the TVA Board took several actions related to the retirement of certain coal-fired units. Upon the completion of a natural gas-fired generation facility at the Paradise Fossil Plant ("Paradise") site, coal-fired Units 1 and 2 at Paradise with a summer net capability of 1,230 MW will be retired, and upon the completion of a natural gas-fired generation facility at the Allen Fossil Plant ("Allen") site, coal-fired Units 1-3 at Allen with a summer net capability of 741 MW will be retired. The TVA Board also approved the retirement of Colbert Units 1-4 and 5 with a total summer net capability of 1,184 MW no later than June 30, 2016, and December 31, 2015, respectively, as well as the retirement of Widows Creek Unit 8 with a summer net capability of 465 MW in the future. See Cleaner Energy Initiatives — Natural Gas-Fired Generation.

Coal-fired plants have been subject to increasingly stringent regulatory requirements over the last few decades, including those of the Clean Air Act ("CAA") and subsequent laws and regulations. Increasing regulatory costs require consideration of whether or not to make the required capital investments to continue operating these facilities. In April 2011, TVA entered into two agreements (collectively, the "Environmental Agreements") to address a dispute under the CAA.  The first agreement is a Federal Facilities Compliance Agreement with the Environmental Protection Agency ("EPA").  The second agreement is with Alabama, Kentucky, North Carolina, Tennessee, and three environmental advocacy groups: the Sierra Club, National Parks Conservation Association, and Our Children’s Earth Foundation.  Under the Environmental Agreements, TVA agreed to retire 18 of its 59 coal-fired units by the end of 2017 and was generally absolved from any liability, subject to certain limitations and exceptions, under the New Source Review ("NSR") requirements of the CAA for maintenance, repair, and component replacement projects that were commenced at TVA's coal-fired units prior to the execution of the agreements. Failure to comply with the terms of the Environmental Agreements would subject TVA to penalties stipulated in the agreements. TVA is taking the actions necessary to comply with the Environmental Agreements. TVA is confident that it has adequate capacity to meet the needs of its customers after these units are retired.

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The following table summarizes the retirement actions TVA is required to take under the Environmental Agreements, and the status of those actions.

Fossil Plant	Total Units	Existing Scrubbers and SCRs(1)	Requirements Under Environmental Agreements	Retirements Implemented or Planned to be Implemented by TVA as a Result of Environmental Agreements
John Sevier	2	None	· Retire two units no later than December 31, 2012	· Retired Units 1 and 2 on December 31, 2012
Johnsonville	10	None	· Retire six units no later than December 31, 2015 · Retire four units no later than December 31, 2017	· Retire six units by December 31, 2015 · Retire four units by December 31, 2017 · Idled Units 7 and 8 effective March 1, 2012 · Idled Units 5 and 6 and Units 9 and 10 on October 1, 2013
Widows Creek	6	Scrubbers and SCRs on Units 7 and 8	· Retire two of Units 1-6 no later than July 31, 2013 · Retire two of Units 1-6 no later than July 31, 2014 · Retire two of Units 1-6 no later than July 31, 2015	· Idled Units 1-6 in October 2011 · Retired Units 3 and 5 on July 31, 2013 · Retired Units 1, 2, 4, and 6 on July 31, 2014

Note

(1)  Selective catalytic reduction systems ("SCR").

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The following table summarizes the additional actions TVA is required to take under the Environmental Agreements, and other coal-fired generation actions taken or to be taken by TVA.

Fossil Plant	Units Impacted	Existing Scrubbers and SCRs	Requirements Under Environmental Agreements	Other Actions Taken or Planned to be Taken by TVA
Allen	3	SCRs on all three units	· Install scrubbers or retire no later than December 31, 2018	· The Board approved the construction of a gas-fired plant at the current location of the Allen coal-fired site · · Retire Units 1-3 after completion of the gas-fired plant
Bull Run	1	Scrubber and SCRs on unit	· Continuously operate current and any new emission control equipment	· Continuously operate existing emission control equipment
Colbert	5	SCR on Unit 5	· Remove from service, control(1), convert(2), or retire Units 1-4 no later than June 30, 2016 · Remove from service, control(1), or retire Unit 5 no later than December 31, 2015 · Control or retire removed from service units within three years	· Idled Unit 5 in October 2013 · Retire Units 1-4 no later than June 30, 2016 · Retire Unit 5 no later than December 31, 2015
Cumberland	2	Scrubbers and SCRs on both units	· Continuously operate existing emission control equipment	· Continuously operate existing emission control equipment
Gallatin	4	None	· Control(1), convert(2), or retire all four units no later than December 31, 2017	· Add scrubbers and SCRs on all four units by December 31, 2017
John Sevier	2	None	· Remove from service two units no later than December 31, 2012 and control(1), convert(2), or retire those units no later than December 31, 2015	· Idled Units 3 and 4 in December 2012 · Retired Units 3 and 4 on June 25, 2014
Kingston	9	Scrubbers and SCRs on all nine units	Continuously operate existing emission control equipment	Continuously operate existing emission control equipment
Paradise	3	Scrubbers and SCRs on all three units	· Upgrade scrubbers on Units 1 and 2 no later than December 31, 2013 · Continuously operate emission control equipment on Units 1-3	· Upgraded scrubbers on Units 1 and 2 in 2012 · Continuously operate emission control equipment on Units 1-3 · The Board approved the construction of a gas-fired plant at the current location of the Paradise coal-fired plant · Retire Units 1 and 2 after completion of the gas-fired plant
Shawnee	2	None	· Control(1), convert, or retire(2) Units 1 and 4 no later than December 31, 2017	· Still evaluating what actions to take with respect to Units 1 and 4 · Idled Unit 10 in October 2010 · Retired Unit 10 on June 30, 2014
Widows Creek	2	Scrubbers and SCRs on Units 7 and 8	· Continuously operate existing emissions control equipment on Units 7 and 8	· Continuously operate existing emissions control equipment on Units 7 and 8 · Idled Unit 8 on October 1, 2014 · Retire Unit 8 in the future

Notes

(1) If TVA decides to add emission controls to these units, TVA must continuously operate the emission controls once they are installed.

(2) Convert to renewable biomass.

As of September 30, 2010, TVA had 14,573 MW (summer net capability) of coal-fired generation. After actions taken to comply with the Environmental Agreements and actions by the TVA Board during 2014, TVA will have 8,089 MW (summer net capability) of coal-fired generation.

TVA is moving towards a more balanced generation plan with lower-cost and cleaner energy generation technologies.TVA’s long-range plans will continue to consider the costs and benefits of significant environmental investments at its remaining coal-fired plants. TVA expects to decide whether to control, convert, or retire its remaining Shawnee units.

Transmission upgrades may be required to maintain reliability when some coal-fired units become inactive. TVA invested $215 million in such upgrades between 2011 and 2014, and estimates future expenditures for transmission upgrades to accommodate inactive coal-fired units to be approximately $230 million for 2015 to 2020. 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.

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Nuclear

TVA has three nuclear sites consisting of six 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.  Statistics for each of these units are included in the table below.

TVA Nuclear Power At September 30, 2014
Nuclear Unit	Status	Nameplate Capacity (MW)	Net Capacity Factor for 2014	Date of Expiration of Operating License	Date of Expiration of Construction Permits
Sequoyah Unit 1	Operating	1,221	85.8	2020*	—
Sequoyah Unit 2	Operating	1,221	86.5	2021*	—
Browns Ferry Unit 1	Operating	1,264	95.2	2033	—
Browns Ferry Unit 2	Operating	1,190	93.5	2034	—
Browns Ferry Unit 3	Operating	1,190	86.1	2036	—
Watts Bar Unit 1	Operating	1,270	85.0	2035	—
Watts Bar Unit 2	Under construction	1,220	—	—	2016

* An extension request has been submitted to the Nuclear Regulatory Commission. See Sequoyah License Renewal below.

Extended Power Uprate. TVA is undertaking an Extended Power Uprate ("EPU") project at Browns Ferry that is expected to increase the amount of electrical generation capacity of its reactors. The NRC license for each reactor must be modified to allow reactor operation at the higher power level.

Because the license amendment requests ("LARs") submitted by TVA at the beginning of this project have been under review for an extended time, TVA’s recent discussions with the NRC on selected technical issues concluded that a more effective strategy to address these issues would be to withdraw the original requests and to resubmit new LARs that would more thoroughly address the issues. The eventual conclusion of the discussions with NRC regarding the technical issues may impact the actual amount of power level increase resulting from the EPU.

Completion of the licensing process will determine the final implementation schedule. TVA expects to begin implementing the EPU project starting in the spring of 2018 for Browns Ferry Unit 3, the fall of 2018 for Unit 1, and spring of 2019 for Unit 2 and expects to complete the project in 2020. The project not only involves engineering analyses, but modification and replacement of certain existing plant components to enable the units to produce the additional power requested by the license amendments.  These improvements will be ongoing in parallel with the NRC’s license amendment review process.  The project is estimated to cost approximately $380 million.

Sequoyah License Renewal. TVA submitted the license renewal applications for Sequoyah Units 1 and 2 to the NRC on January 7, 2013. If approved, the licenses for both units would be extended by an additional 20 years to 2040 for Unit 1 and 2041 for Unit 2. The NRC's review of the applications is expected to take up to three years after their submission. 

On August 26, 2014, the NRC approved a final rule on the environmental effects of continued storage of spent nuclear fuel and terminated a two-year suspension of final licensing actions for nuclear power plants and renewals. Issuance of this rule may help alleviate some issues in the relicensing processes related to Sequoyah. See Note 21 —Legal Proceedings —Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage for additional information, which information is incorporated herein by reference.

Operational Challenges. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources and Key Initiatives and Challenges —Generation Resources, for a discussion of challenges associated with the nuclear program, which discussions are incorporated herein by reference.

Other Nuclear Matters. See Fuel Supply — Nuclear Fuel below for a discussion of spent nuclear fuel and low-level

radioactive waste, Note 21— Contingencies for a discussion of TVA's nuclear decommissioning liabilities and the related trust and nuclear insurance, and Note 21— Legal Proceedings for a discussion of legal and administrative proceedings related to TVA's nuclear program, which discussions are incorporated herein by reference.

Hydroelectric and Other Renewable Energy Resources

Conventional Hydroelectric Dams. TVA maintains 29 conventional hydroelectric dams with 109 generating units throughout the Tennessee River system and one pumped-storage facility for the production of electricity.  At September 30, 2014, these units accounted for 5,418 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, and

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the need for water for competing water management objectives.  The amount of electricity generated also depends on the availability of TVA's hydroelectric generation plants.  When these factors are unfavorable, TVA must increase its reliance on higher cost generation plants and purchased power.  In addition, eight U.S. Army Corps of Engineers dams on the Cumberland River contribute to the TVA power system.  See Weather and Seasonality andItem 7,Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Dam Safety Assurance Initiatives.

In 1992, TVA began a Hydro Modernization Program to address reliability issues related to its conventional hydroelectric units and Raccoon Mountain Pumped-Storage Plant ("Raccoon Mountain"). At September 30, 2014, modernization had been completed on 56 conventional hydroelectric units and four pumped-storage units. These modernization projects resulted in 427 MW of increased capacity on the conventional units, with an average efficiency gain of approximately five percent. Hydroelectric generation will continue to be an important part of TVA's energy mix. TVA, through its Hydro Modernization Program, continues to assess its remaining conventional hydroelectric units for opportunities to improve reliability and increase capacity.

Raccoon Mountain Pumped-Storage Plant.  The four units at Raccoon Mountain were placed in service during 1978 and 1979. The units, with a total net summer capability of 1,616 MW, are utilized to balance the transmission system as well as generate power.

Units 1-4 were taken out of service for maintenance activities in 2012 after an inspection of the turbines in each unit identified cracking in the rotor poles and the rotor rims. All four units have subsequently completed maintenance overhauls to correct these cracking problems.  However, an unrelated issue was identified in certain oil-filled power cables which convey power out of the facility, resulting in TVA limiting service to three units until the issue is resolved. As of September 30, 2014, three of the four Raccoon Mountain units were in service. The return to service date for the fourth unit is estimated to be in the third quarter of 2015.

Other Renewable Energy Resources. TVA's renewable energy portfolio includes both TVA-owned assets and renewable energy purchases. TVA owns 16 solar sites, capability for digester gas and biomass cofiring, and three wind turbines. At September 30, 2014, the wind turbines were not operational and were not available to provide any summer net capability.  The Electric Power Research Institute ("EPRI") is currently undertaking a research project to assess the condition of the three TVA-owned turbines and to evaluate options for the future of the wind turbines.  Results of the project are expected to be completed in the first quarter of 2015. The digester gas cofiring capability is accounted for as coal-fired generation summer net capability. The solar sites provide less than one MW of summer net capability.

Natural Gas and/or Oil-Fired

At September 30, 2014, TVA operated 98 combustion turbine power blocks, 87 simple-cycle units and 11 combined-cycle power blocks. The 87 simple-cycle units provide a maximum of 5,388 MW of summer net capability. The 11 combined-cycle power blocks provide a maximum of 3,854 MW of summer net capability. Eighty of the simple-cycle units and one combined-cycle power block are fueled by either natural gas or fuel oil. The remaining seven simple-cycle units as well as the 10 combined-cycle power blocks are fueled by natural gas only. Seventy-six of the simple-cycle units are capable of quick-start response allowing full generation capability in approximately 10 minutes. TVA uses simple-cycle units as peaking or backup units.

See Item 2, Properties — Generating Properties for a discussion of lease arrangements into which TVA has entered in connection with certain of the combustion turbine units. Because of TVA's strategy of portfolio diversification and reducing air emissions, TVA may decide to make further strategic investments in natural gas-fired facilities in the future by purchase, construction, and/or lease.

Diesel Generators

At September 30, 2014, TVA had one diesel generator plant consisting of five units, and these facilities accounted for 9 MW of summer net capability.

Purchased Power and Other Agreements

TVA acquires power from a variety of power producers through long-term and short-term power purchase agreements as well as through power spot market purchases.  During 2014, TVA acquired approximately 11 percent of the power that it purchased on the power spot market, approximately one percent through short-term power purchase agreements (agreements with a duration of one year or less but longer than the term of spot-market purchase), and approximately 88 percent through long-term power purchase agreements (agreements with a duration of more than one year).

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A portion of TVA’s capability provided by power purchase agreements is provided under contracts that expire between 2015 and 2032, and the most significant of these contracts are described below.

Power Purchase Contracts (Excluding Wind Contracts) At September 30, 2014
Type of Facility	Location	Summer Net Capability (MW)	Contract Termination Date
Lignite	Mississippi	440	2032
Natural gas	Alabama	720	2023
Natural gas	Mississippi	675	2015

Under federal law, TVA is required to purchase energy from qualifying cogenerators and small power producers at TVA's avoided cost of self-generating or purchasing this energy from another source.  As of September 30, 2014, there were six suppliers, with a combined capacity of 890 MW, whose power TVA purchases under this law.

As of September 30, 2014, TVA was a party tocontracts with eight wind farms for the purchase of energy. Energy is currently provided to TVA under all contracts.  The first began providing 300 MW (nameplate capacity) under a twenty-year contract from a wind farm in Illinois in May 2010.  TVA currently does not purchase the renewable attributes for this energy but has the opportunity to obtain them in the future. The other seven contracts provide TVA with an additional 1,215 MW (nameplate capacity) that include renewable attributes.  These wind farms are located in Illinois, Kansas, and Iowa.  TVA may work with counterparties to renegotiate or even terminate existing arrangements based on its evaluation of the economics of the contracts given that bringing power from distant locations raises transmission issues and costs.

Wind Contracts As of September 30, 2014
Location of Wind Farm	Contracted Nameplate Capacity (in MW)	Date Delivery Began	Contract Termination Date
Illinois	300*	2010	2030
Iowa	198	2010	2031
Iowa	101	2012	2030
Kansas	201	2012	2032
Kansas	165	2013	2032
Illinois	150	2012	2032
Illinois	200	2012	2032
Illinois	200	2013	2033

Note

*TVA is currently purchasing the energy output of this 300 MW of generation. The owner of the facility retains the renewable attributes, but TVA has the option to purchase the renewable attributes of this generation in the future.

In addition, TVA has contracted for 27 MW of nameplate renewable energy capacity from 15 wind turbine generators located on Buffalo Mountain near Oak Ridge, Tennessee, 4.8 MW of nameplate capacity from a landfill gas facility near Knoxville, Tennessee, and 4.5 MW of nameplate capacity from a solar farm in Haywood County, Tennessee.

Technology advancements may be needed to address some of the operational issues associated with intermittent renewable energy sources in the future.  Regional differences and geographic limitations play a primary role in the types and amount of renewable and clean energy developed across the country.  Within the area served by TVA, the most viable renewable resources are hydroelectric, biomass (solid and methane recovery), solar, and wind.  Known wind resource potential has increased recently due to studies showing reasonable wind speeds available at higher elevations in the TVA service area, and these resources may be a source of energy for TVA in the future. 

During the past three years, TVA supplemented its power generation through power purchases as follows:

Purchased Power* For the years ended September 30
	2014		2013		2012
Millions of kWh	18,740		18,848		25,294
Percent of TVA’s total power supply	11.6	%	11.4	%	15.0	%

Note

* Purchased power amounts include generation from Caledonia Combined-Cycle Gas Plant, which is currently a leased facility operated by TVA.

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Cleaner Energy Initiatives

TVA intends to balance production capabilities with power supply requirements by promoting the conservation and efficient use of electricity and, when necessary, buying, building, and/or leasing assets or entering into power purchase agreements.  TVA also intends to employ a diverse mix of energy generating sources and is working toward obtaining greater amounts of its power supply from clean (low or zero carbon emitting) resources.

Nuclear Generation

Watts Bar Unit 2. Construction of Watts Bar Unit 2 is continuing in accordance with the schedule and budget expectations approved by the TVA Board in April 2012. The total estimated cost of completion is in the range of $4.0 billion to $4.5 billion. TVA plans to bring Watts Bar Unit 2 into commercial operation by December 2015.

The regulatory reviews associated with the issuance of an NRC operating license for Watts Bar Unit 2 are continuing. The NRC issued an extension to the Watts Bar Unit 2 construction permit on November 21, 2013. The revised permit expires on September 30, 2016. The NRC reviews of TVA’s actions associated with post-Fukushima requirements are underway and are not currently anticipated to affect the timely issuance of an operating license. Resolution of the waste confidence issue helped mitigate a significant risk related to meeting the completion date of Watts Bar Unit 2. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Generation Resources — Watts Bar Unit 2 and — Waste Confidence Rule, which discussions are incorporated herein by reference.

Bellefonte Unit 1. Although work on the Bellefonte Unit 1 site was slowed in 2014, TVA believes that near-term budgeting and staffing levels should be sufficient to preserve Bellefonte for potential future development. TVA plans to utilize its integrated resource planning process to help determine how Bellefonte best supports TVA's overall efforts to continue to meet customer demand with low-cost, reliable power.

Other Nuclear Initiatives. TVA is preparing an early site permit license application to the NRC to license small modular reactors ("SMRs") at TVA’s Clinch River Site in Oak Ridge, Tennessee. See Note 21 — Legal Proceedings — Administrative Proceedings Regarding Watts Bar Unit 2 and Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives — Generation Resources — Small Modular Reactors.

Natural Gas-Fired Generation

Part of TVA’s strategy of portfolio diversification and air emissions reductions involves the addition of natural gas-fired plants to its generation fleet. At its November 14, 2013 meeting, the TVA Board approved the completion of a natural gas-fired facility with an expected generation capacity of approximately 1,000 MW at TVA’s Paradise site. A lawsuit has been filed challenging TVA's Paradise decision. See Note 21— Legal Proceedings — National Environmental Policy Act Challenge at Paradise Fossil Plant. An injunction or court order that delays TVA's plans at Paradise could increase the project's cost. On August 21, 2014, the TVA Board approved the construction of a natural gas-fired facility also with an expected generation capacity of approximately 1,000 MW at the Allen site. Upon completion of each facility, existing coal-fired units at each site will be retired with the exception of Paradise Unit 3, which would continue to be operated on the Paradise site. See Power Supply — Coal-Fired.

Energy Efficiency, Demand Response, and Renewable Energy Programs

TVA, in cooperation with its customers, continues to implement a broad portfolio of energy efficiency, demand response, and system load enhancement programs and projects designed to help reduce long-term energy supply costs in the TVA service area through EnergyRight^® Solutions (“ERS”) programs.  TVA realized 553 gigawatt hours ("GWh") and 521 GWh of energy efficiency savings in 2014 and 2013, respectively. ERS efforts are expected to remain a focus of TVA and are playing an important role in the development of the Integrated Resource Plan currently under way.

ERS programs continue to be revamped and expanded with the completion of the In-Home Energy Evaluation program in 2014 after achieving over 85,000 home energy audits and the introduction the new eScore program design utilizing a wireless data collection system to more effectively document and process residential evaluation data. TVA anticipates implementation of the eScore design throughout the Tennessee Valley in December 2014 with greater focus on establishing of a long-term efficiency improvement relationship with participating homeowners. ERS also continues to expand participation in demand reduction efforts such as dispatchable voltage regulation which contribute to TVA’s management of peak loads.

TVA's Green Power Switch^® ("GPS") program is a voluntary program that supports the production of renewable energy by allowing consumers to purchase renewable energy. The GPS program provided approximately 192,000 MWh of renewable energy in 2013. TVA is continuing to refine the program, which was introduced in 2000, by testing two additional customer options within limited geographical regions of TVA’s service area. The two pilot options are testing customer demand for a 100- percent solar option sourced from TVA's growing Green Power Providers ("GPP") supply as well as a lower-priced bulk option for larger commercial and industrial customers. Supply for the bulk option is sourced from TVA-contracted renewable energy credits

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("RECs"), an environmental commodity that represents the environmental attributes of renewable energy, in the greater Southeastern region.

In 2013, TVA replaced its Generation Partners ("GP") program with the GPP program for the purpose of encouraging the development of small-scale solar, wind, biomass, and hydroelectric generation systems across the Tennessee Valley that are 50 kilowatts ("kW") or less. The GPP program is fully subscribed for CY 2014. As of September 30, 2014, the combined participation for the GP and GPP programs comprised more than 88 MW of operating generation with 5.7 MW of additional approved capacity in the GPP program that has yet to become operational.

The Renewable Standard Offer ("RSO") program is a voluntary program that began in October 2010 to increase the amount of renewable energy generated in TVA's service territory. This program offers pre-set prices, terms, and conditions for power generated by selected, commercially available renewable energy technologies. Solar, wind, and specific biomass projects are included in the program. Projects must be greater than 50 kW, but no greater than 20 MW in nameplate capacity. TVA demonstrated its continued commitment to renewable energy by offering to purchase an additional 100 MW under the RSO program in CY 2014. As of September 30, 2014, TVA has over 34 MW of operating generation and an additional196 MW under application or contract not yet operating. RSO projects approved in CY 2014 have a contract term of 20 years and a new price structure updated to be compatible with the existing portfolio.

The Solar Solution Initiative ("SSI") is a targeted incentive program that aims to support the existing local solar industry, while also serving as a recruitment tool for new industry in the Tennessee Valley region, by retaining and adding investment and jobs. The program provides incentive payments for mid-sized (greater than 50 kW up to 1 MW) solar projects in TVA's RSO program if the projects use local certified installers in the Tennessee Valley region. During CY 2014, the SSI program was expanded to 16 MW. The program currently has over 3 MW of operating generation. Applications will continue to be accepted and placed on the waiting list until 16 MW is contracted.

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.  The following table summarizes TVA’s expenses for various fuels for the years indicated:

Fuel Expense for TVA-Owned Facilities* For the years ended September 30 (in millions)
	2014		2013		2012
Coal	$	1,873	$	1,890	$	1,824
Natural gas	531		504		527
Fuel oil	48		36		46
Nuclear fuel	307		317		319
Total fuel	$	2,759	$	2,747	$	2,716

Note

* Excludes effects of the fuel cost adjustment deferrals and amortization on fuel expense in the amounts of $(29) million, $73 million, and $(36) million for the years ended September 30, 2014, 2013, and 2012, respectively.

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The following table indicates TVA’s average fuel expense by generation type for the years indicated:

Fuel Expense Per kWh(1)(2) For the years ended September 30 (cents/kWh)
	2014	2013	2012
Coal	3.05	3.07	3.18
Natural gas and fuel oil	4.30	3.89	3.19
Nuclear	0.57	0.61	0.58
Average fuel cost per kWh net thermal generation from all sources	2.14	2.15	2.08

Note

(1) Excludes effects of the fuel cost adjustment deferrals and amortization on fuel expense.

(2) In 2012, TVA began allocating 50 percent of its Financial Trading Program ("FTP") gains and losses to fuel expense. In 2013, the allocation changed to 70 percent of FTP gains and losses being allocated to fuel expense and 30 percent of FTP gains and losses being allocated to purchased power expense. In 2014, the allocation changed to 80 percent of FTP gains and losses being allocated to fuel expense and 20 percent of FTP gains and losses being allocated to purchased power expense.

In addition to TVA-owned generating facilities, TVA operates a plant under an operating lease agreement and also has tolling agreements under which it obtains electricity from outside suppliers. Under these agreements, TVA supplies the fuel to produce electricity. The following table indicates the cost of fuel supplied by TVA and also the average fuel expense per kWh for the years indicated:

Natural Gas Purchases for Non-TVA Owned Facilities(1) For the years ended September 30
	2014		2013		2012
Cost of fuel (in millions)	$	160	$	138	$	255
Average fuel expense (cents/kWh)	3.56		2.95		2.36

Note

(1) In 2012, TVA began allocating 50 percent of its FTP gains and losses to fuel expense. In 2013, the allocation changed to 70 percent of FTP gains and losses being allocated to fuel expense and 30 percent of FTP gains and losses being allocated to purchased power expense. In 2014, the allocation changed to 80 percent of FTP gains and losses being allocated to fuel expense and 20 percent of FTP gains and losses being allocated to purchased power expense.

Coal

Coal consumption at TVA’s coal-fired generating facilities during 2014 and 2013 was approximately 31 million tons and 32 million tons, respectively.  At both September 30, 2014, and September 30, 2013, TVA had 29 days of system-wide coal supply at full burn rate with net book values of $361 million and $374 million, respectively.

TVA utilizes both short-term and long-term (longer than one year) coal contracts.  During 2014, long-term contracts made up 91 percent of coal purchases and short-term contracts accounted for the remaining nine percent.  TVA plans to continue using contracts of various lengths, terms, and coal quality to meet its expected consumption and inventory requirements.  During 2014, TVA purchased coal by basin as follows:

• 47 percent from the Illinois Basin;

• 36 percent from the Powder River Basin in Wyoming;

• 14 percent from the Uinta Basin of Utah and Colorado; and

• three percent from the Appalachian Basin of Kentucky, Pennsylvania, Tennessee, Virginia, and West Virginia.

Generally, total system coal inventories were at or above target levels for most of 2014 due to lower than planned coal-fired generation requirements. However, due to persistent performance issues with certain rail companies, inventories at some facilities fell below minimum levels during 2014. Additionally, some coal-fired units were placed in reserve in the spring to conserve coal for summer peak use.  The following table indicates the delivery methods TVA utilizes for its coal supply:

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Percentage of Coal Supply Delivery Methods For the years ended September 30
	2014		2013
Rail	23	%	21	%
Barge	16	%	13	%
Barge and rail combination	54	%	60	%
Truck	7	%	6	%

Natural Gas and Fuel Oil

During 2014, TVA purchased a significant amount of its natural gas requirements from a variety of suppliers under contracts with terms of up to two years and purchased substantially all of its fuel oil requirements on the spot market. Previously, spot market volatility was managed through TVA’s FTP. However, management is currently evaluating the future use of financial instruments for price hedging.

The net book value of TVA’s natural gas inventory was $9 million and $7 million at September 30, 2014, and 2013, respectively. The net book value of TVA’s fuel oil inventory was $100 million and $113 million at September 30, 2014, and 2013, respectively. At September 30, 2014, all but 17 of the combustion turbine units that TVA operates were dual-fuel capable, and TVA has fuel oil stored on each of these sites for its dual-fuel combustion turbines as a backup to natural gas.

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 five-year (2015-2019) 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.  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 United States Enrichment Corporation ("USEC") was one of TVA’s suppliers of enrichment services for uranium for fueling TVA's nuclear units.  On May 24, 2013, USEC announced the cessation of enrichment activities at its Paducah, Kentucky facility.  TVA has sufficient nuclear fuel inventory available to mitigate near-term supply risks. 

TVA, the Department of Energy ("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 is expected to continue to be used to reload the Browns Ferry reactors through at least 2016. BLEU fuel was loaded into Sequoyah Unit 2 three times but is not expected to be used in the Sequoyah reactors in the future.

Under the terms of an interagency agreement between the DOE and TVA, in exchange for supplying highly enriched uranium materials for processing into usable BLEU fuel for TVA, the DOE participates in the savings generated by TVA’s use of this blended nuclear fuel.  See Note 1 — Blended Low-Enriched Uranium Program for a more detailed discussion of the BLEU project.

TVA owns all nuclear fuel held for its nuclear plants.  At both September 30, 2014, and 2013, the net book value of this nuclear fuel was $1.3 billion.

Mixed Oxide Nuclear Fuel. Under the DOE Surplus Plutonium Disposition ("SPD") Program, mixed oxide ("MOX") fuel would be fabricated with surplus plutonium and depleted uranium as a replacement for commercial uranium fuel. In February 2010, the DOE and TVA entered into an interagency agreement to evaluate the potential use of MOX fuel in reactors at Browns Ferry and Sequoyah. As part of the evaluation of MOX fuel, TVA is participating as a cooperating agency in the DOE's development of a supplemental EIS that addresses the potential use of MOX fuel in the TVA reactors. TVA could make a decision in 2015 on whether to continue to pursue the use of MOX fuel. At the earliest, based on the expected production rate of MOX fuel, TVA could start using a small number of MOX fuel assemblies in TVA reactors after 2020. TVA's three criteria for implementing MOX fuel are that it must be environmentally and operationally safe; it must be economical compared to other nuclear fuel used by TVA; and it must be licensed by the NRC for use.  If TVA decides to use MOX fuel and the NRC approves its use, some changes in the operation of the reactors are expected and additional equipment may be required. As TVA continues to evaluate fuel options, current fuel supply plans do not include MOX fuel.

Low-Level Radioactive Waste.  Low-level radioactive waste ("radwaste") results from the normal operation of nuclear electrical generation units and includes such materials as disposable protective clothing, mops, and filters. TVA sends

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shipments of radwaste to burial facilities in Clive, Utah and Andrews, Texas.  TVA is capable of storing some radwaste at its own facilities for an extended period of time, if necessary.

Spent Nuclear Fuel.  Under the Nuclear Waste Policy Act of 1982, generators of nuclear energy were historically required to pay a fee of one-tenth of a cent per kilowatt-hour into the DOE nuclear waste fund. TVA’s annual payments into this fund ranged from $50 million to $55 million in recent years. In November 2013, the U.S. Court of Appeals for the District of Columbia Circuit ("D.C. Circuit") ordered the DOE to stop collecting nuclear waste fees until either (1) the DOE complies with the Nuclear Waste Policy Act of 1982, or (2) the U.S. Congress enacts an alternative waste management plan. In accordance with the court’s order, the DOE submitted a proposal to the U.S. Congress in January 2014 to change the nuclear waste fee to zero, and as of May 16, 2014, the DOE ceased collecting this fee. TVA saved approximately $20 million in 2014, and if the fee remains at zero, TVA estimates that it will save approximately $52 million in 2015. Any such savings will be passed on to TVA’s customers through the fuel cost adjustment.  The Sequoyah and Browns Ferry dry cask storage facilities have been in use since 2004 and 2005, respectively, and are expected to provide storage capacity through 2026 at Sequoyah and 2018 at Browns Ferry.  Watts Bar has sufficient storage capacity in its spent fuel pool though 2016. TVA is currently constructing an independent spent fuel installation pad for spent fuel storage at Watts Bar, and cask loading is scheduled in the spring of 2016.  See Power Supply — Nuclear.

To recover the cost of providing long-term, on-site storage for spent nuclear fuel, TVA filed a breach of contract suit against the United States in the Court of Federal Claims in 2001, and as a result, TVA received approximately $35 million for costs incurred through 2004. By agreement with the United States, TVA subsequently recovered an aggregate of approximately $72 million to offset dry cask storage costs incurred from 2005 through 2010.  TVA entered into a settlement agreement with the United States in July 2011 that delineates recoverable and non-recoverable costs and sets forth a claim submittal and review process. This settlement agreement expired on December 31, 2013, but was extended through December 31, 2016. In February 2013, TVA received $12 million for its 2011 claim, and in January 2014, TVA received nearly $17 million for its 2012 claim. In July 2014, TVA submitted a claim of nearly $17 million for 2013 costs, reported in Accounts receivable, net. For 2014, TVA has incurred approximately $18 million in costs, reported in Other long-term assets.

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 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 tritium-producing rod over the period when irradiation has occurred.

In general, tritium-producing rods 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 tritium-producing rods into the reactor during each refueling outage.  Irradiating the tritium-producing rods 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.

Transmission

The TVA transmission system is one of the largest in North America.  TVA’s transmission system has 69 interconnections with 12 neighboring electric systems, and delivered nearly 161 billion kWh of electricity to TVA customers in 2014.  In carrying out its responsibility for transmission grid reliability in the TVA service area, TVA has operated with 99.999 percent reliability over the last 15 years in delivering electricity to customers. See Item 2, Properties — Transmission Properties.

To the extent that federal law requires access to the TVA transmission system, TVA offers transmission services to others to transmit power at wholesale rates 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 functions from its marketing functions.

TVA is subject to federal reliability standards that are set forth by the North American Electric Reliability Corporation ("NERC") and approved by the 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 continue to become more complex and stringent for transmission systems. At present there are approximately 100 mandatory standards subject to enforcement containing approximately 1,200 requirements and sub-requirements that must be met. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives and Challenges — Regulatory Compliance — Transmission Issues.

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Weather and Seasonality

Weather affects both the demand for and the market prices of electricity.  TVA uses degree days to measure the impact of weather on its power operations.  Degree days measure the extent to which average temperatures in the five largest cities in TVA's service area vary from 65 degrees Fahrenheit.  During 2014, TVA had 366, or 11 percent, more heating degree days and 136, or eight percent, more cooling degree days than in 2013.

	2014	Percent Change	2013	Percent Change	2012
Combined degree days (normal 5,223)	5,597	9.9%	5,095	8.1%	4,714

TVA’s power system is generally a dual-peaking system where the demand for electricity peaks during the summer and winter months to meet cooling and heating needs.  TVA met an all-time summer peak demand of 33,482 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.  As a result of a cold wave during January 2014, TVA set a new total daily energy record of 703 GWh on January 7, 2014. Also, a new total weekly energy demand record of 4,632 GWh was set for the seven-day period ended January 10, 2010, when TVA experienced an average demand of 27,574 MW per hour for the entire week.

Rainfall totals in the Upper Basin of the Tennessee Valley were near normal, however significantly less than was observed during 2013. Rainfall in the Upper Basin of the Tennessee Valley was 97 percent of normal for 2014 and 124 percent of normal in 2013. Also, runoff was 90 percent of normal in 2014 and 143 percent of normal in 2013. Runoff is the amount of rainfall that is not absorbed by vegetation or the ground and actually reaches the rivers and reservoirs that TVA manages. TVA’s conventional hydroelectric generation decreased 25 percent in 2014 as compared to 2013, and increased 39 percent in 2013 as compared to 2012. Conventional hydroelectric generation was approximately 96 percent of normal in 2014 and 127 percent of normal in 2013.

Competition

TVA provides electricity in a service area that is largely free of competition from other electric power providers.  This service area is defined primarily by two provisions of law: the fence and the anti-cherrypicking provision.  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.

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 Congressional legislation at some time in the future.

Research and Development

TVA makes annual investments in science and technological innovation to help the agency meet future business and operational challenges. Each year TVA’s annual research portfolio and research strategic plan is updated based on a broad range of operational and industry drivers that help assess key technology gaps, performance issues, or other significant issues that should be addressed through research and development. Core research activities directly support optimization of TVA's generation and delivery assets, air and water quality, and clean energy integration. Additional focus is placed on emerging technological advances in SMRs, energy utilization technologies, and distributed energy resources.

In the area of energy utilization, TVA evaluates emerging energy efficiency and load management technologies for market and program readiness. TVA's efforts are directed towards demonstrating and validating the performance, reliability, and consumer acceptance of new efficiency technology as well as the value of energy efficiency and load management technologies for the consumer, the LPC, and TVA. TVA also coordinates activities with EPRI and industry stakeholders related to transportation electrification to support operational fleet requirements and the needs of LPCs to provide guidance on matters of plug-in electric vehicle grid integration and readiness for transportation electrification technologies.

SMRs are a next-generation nuclear technology with potential for improved safety and increased flexibility while providing an important option for clean, reliable energy for TVA’s customers. TVA is preparing an early site permit application to the NRC to license SMRs at its Clinch River Site in Oak Ridge, Tennessee. TVA’s project has a great deal of flexibility at this early stage of new technology development and TVA will be ready to implement whatever decision is in the best interests of the people of the Tennessee Valley. See Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives — Generation Resources — Small Modular Reactors.    

TVA clean energy research seeks to understand the scope and impact of integrating distributed energy resources ("DER") on operations and business economics and to develop strategies for adapting to the evolving electricity landscape in the Tennessee Valley. Of particular interest is modeling existing and expected solar power deployments in the Tennessee Valley to evaluate the full extent of system impacts of the resources. Economic analyses will also be conducted to value the DER to the

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owner, the LPC system, and subsequently the bulk system as a whole. See See Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations — Key Initiatives — Generation Resources — Distributed Generation.

Investments in TVA’s research portfolio are supported through partnership and collaboration with local power companies, EPRI and other research consortiums, the DOE and other federal agencies, national labs, peer utilities, universities, and industry vendors and participation in professional societies.

Flood Control Activities

The Tennessee River watershed has one of the highest annual rainfall totals of any watershed in the United States, averaging 51 inches per year. From October 1, 2013, through September 30, 2014, 49 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 the tributary and main stem 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.

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, and, consistent with these primary purposes, 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 and nuclear power plants.  TVA’s Environmental Policy, which was adopted by the TVA Board in 2008, provides objectives for an integrated approach related to providing cleaner, reliable, and affordable energy, supporting sustainable economic growth, and engaging in proactive environmental stewardship.  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 also manages approximately 11,000 miles of shoreline, 650,000 surface acres of reservoir water, and 293,000 acres of reservoir lands for cultural and natural resource protection, recreation, and other purposes.

Strategic guidance for carrying out many of TVA's essential stewardship responsibilities is provided in TVA's Natural Resource Plan ("NRP"). The NRP, issued in August 2011, serves as a 20-year guide for TVA's essential stewardship efforts in managing biological resources (plants, animals, and aquatic species); cultural resources (archaeological sites, historical sites, and artifacts); recreation; water resources; reservoir lands planning; and public engagement. The plan will also guide TVA in achieving the objectives of its Environmental Policy for a more systematic and integrated approach to fulfilling its essential stewardship responsibilities. The NRP was developed with public input including participation from federal and state resource management agencies and the RRSC. Members of the RRSC, established in March 2000, represent public and private stakeholders who benefit from TVA’s management of the river system. They provide recommendations on stewardship activities, including reservoir operations, public-land planning and management, water supply, recreation, infrastructure operation and maintenance, and emergency preparedness. TVA intends to review and update the NRP approximately every five years.

Economic Development Activities

Since its creation in 1933, TVA has promoted the development of the Tennessee Valley. Economic development, along with energy production and environmental stewardship, is one of the integrated 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 prepare communities in the Tennessee Valley for 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 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.

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TVA's economic development efforts helped recruit or expand over 194 companies into the TVA service area during 2014. These companies announced capital investments of approximately $8.5 billion and the expected creation and/or retention of over 60,300 jobs.

Regulation

Congress

TVA exists pursuant to legislation 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 United States’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 United States, 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 generally includes 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 Section 210 of the FPA, TVA can be ordered to interconnect its transmission facilities with the electrical facilities of qualified generators and other electric utilities that meet certain requirements.  It must be found that the requested interconnection is in the public interest and would encourage conservation of energy or capital, optimize efficiency of facilities or resources, or improve reliability.  The requirements of Section 212 of the FPA concerning the terms and conditions of interconnection, including reimbursement of costs, must also be met.

Under Section 211 of the FPA, TVA can be ordered to transmit wholesale power provided that the order (1) does not impair the reliability of the TVA or surrounding systems and (2) meets the applicable requirements of Section 212 concerning terms, conditions, and rates for service.  Under Section 211A of the FPA, TVA is subject to FERC review of the transmission rates and the terms and conditions of service that TVA provides others to ensure comparability of treatment of such service with TVA’s own use of its transmission system and that the terms and conditions of service are not unduly discriminatory or preferential.  The anti-cherrypicking provision of Section 212 of the FPA precludes TVA from being ordered to wheel another supplier’s power to a customer if the power would be consumed within TVA’s defined service territory.

Sections 221 and 222 of the FPA, applicable to all market participants, including TVA, prohibit (1) 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 (2) using manipulative or deceptive devices or contrivances in connection with the purchase or sale of power or transmission services subject to FERC’s jurisdiction .

Under Section 215 of the FPA, TVA must comply with certain standards designed to maintain transmission system reliability.  These standards are approved by FERC and enforced by the NERC.

Section 206(e) of the FPA provides FERC with authority 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.

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Section 220 of the FPA provides FERC with authority 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.

Under Sections 306 and 307 of the FPA, FERC may investigate electric industry practices, including TVA’s operations previously mentioned that are subject to FERC’s jurisdiction.

Under Sections 316 and 316A of the FPA, FERC has authority to impose civil penalties of up to $1 million a day for each violation on entities subject to the provisions of Part II of the FPA, which includes the above provisions 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.

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 which 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.

States

The Supremacy Clause of the U.S. Constitution prohibits states, without congressional 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.

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.  Section 13 of the TVA Act does, however, require TVA to make tax equivalent payments to states and counties in which TVA conducts power operations or in which TVA has acquired power-producing 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.

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"), sulfur dioxide ("SO₂"), nitrogen dioxide ("NO₂"), 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 a NAAQS within its borders. These plans impose limits

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on emissions from pollution sources, including TVA fossil fuel-fired plants. Areas meeting a NAAQS are designated attainment areas. Areas not meeting a NAAQS are designated nonattainment areas, and more stringent requirements apply in those areas. This includes stricter controls on industrial facilities and more complicated permitting processes. TVA coal-fired plants can be impacted by these requirements. As NAAQS become more stringent, utilities are expected to come under increasing pressure to further reduce emissions from their existing fossil fuel generating plants.

New Source Review. The NSR provisions of the CAA require that a permit be obtained prior to constructing new major air emission sources or making major modifications to existing air pollution sources. Major modifications are non-routine physical or operational changes that increase the emissions from an air emission source above specified thresholds. The EPA and environmental groups have been actively pursuing NSR enforcement actions against electric utilities since 1999, alleging that typical plant maintenance activities require NSR permits. If violations are found to have occurred, the EPA or state enforcement authorities could require the installation of new pollution control equipment and could impose fines and penalties. The Environmental Agreements resolved most past NSR claims that TVA faced. The Environmental Agreements did not resolve possible claims based on increases in greenhouse gas ("GHG") and sulfuric acid mist, and these claims could still be pursued in the future.

Cross State Air Pollution Rule. In July 2011, the EPA announced the final Cross State Air Pollution Rule ("CSAPR"), a more stringent rule to replace the existing Clean Air Interstate Rule ("CAIR"), to regulate SO₂ and NO_x emissions from upwind states. CSAPR was stayed in December 2011 and vacated by the D.C. Circuit in August 2012. On April 29, 2014, the U.S. Supreme Court reversed the vacatur, and then on October 23, 2014; the D.C. Circuit granted the EPA’s motion to lift the stay on CSAPR. CSAPR requirements are expected to begin with Phase I on January 1, 2015, followed by Phase II on January 1, 2017. The EPA must also take actions to address allowance allocations and administrative issues. TVA is analyzing the implications of the lift of the CSAPR stay and possible impacts to TVA. TVA’s significant reductions in SO₂ and NO_x emissions and planned future reductions will aid in compliance with CSAPR.

The EPA is also developing a new transport rule to address attainment of the 8-hour ozone standard. Until the EPA proposes a new transport rule, it is not possible to predicts its impacts on TVA.

Hazardous Air Pollutants from Industrial, Commercial, and Institutional Boilers. In March 2011, the EPA published a final rule to establish standards for hazardous air pollutants emitted from industrial, commercial, and institutional boilers and process heaters. The final rule, effective in the second quarter of 2014, has had minor impacts for some of TVA’s startup and auxiliary boilers at its plants. While all plant startup and auxiliary boilers are expected to be exempt from the emission limits due to their limited use, most boilers will be subject to scheduled tuneups to ensure optimized combustion, and TVA will be required to follow work practice standards in order for the boilers to be exempt from emission standards.

Mercury and Air Toxic Standards for Electric Utility Units. In April 2012, the EPA promulgated a final rule establishing standards for hazardous air pollutants emitted from steam electric utilities. The rule requires additional controls for hazardous air pollutants, including mercury, non-mercury metals, and acid gases, for some of TVA’s coal-fired units by 2015-2016. TVA may choose to idle or retire some units in lieu of investing in additional controls and may in some cases construct replacement generation. The rule was challenged in court, and was upheld on April 15, 2014, by the D.C. Circuit.

The Environmental Agreements. See Note 21—Legal Proceedings—Environmental Agreements for a discussion of the Environmental Agreements, which discussion is incorporated herein by reference.

Acid Rain Program. Congress established the Acid Rain Program to achieve reductions in emissions of SO₂ and NO_x, the primary causes of acid rain. The program includes a cap-and-trade emission reduction program for SO₂ emissions from power plants. TVA continues to reduce SO₂ and NO_X emissions from its coal-fired plants, and the SO₂ 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 NO_x emissions by either the CAIR or CSAPR program are expected to be more stringent than the Acid Rain Program. Therefore, TVA forecasts that the Acid Rain Program will have no impact on TVA other than administrative reporting.

Regional Haze Program. In June 2005, the EPA issued the Clean Air Visibility Rule, amending its CY 1999 regional haze rule, which had established timelines for states to improve visibility in national parks and wilderness areas throughout the United States. Under the amended rule, certain types of older existing sources are required to install best available retrofit technology. To comply with this requirement, certain utilities, including TVA, may have to install additional controls for particulate matter, SO₂, and NO_x emissions or agree to lower emission limits at plants equipped with such controls. TVA anticipates that this program will impact only Colbert Unit 5, which was idled in October 2013 and will be retired on or before December 31, 2015.

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 SO₂ and NO_x emissions can adversely affect opacity performance, and TVA and other utilities are addressing this issue. The evaluation of a utility’s compliance with opacity requirements is coming under increased scrutiny, especially compliance during periods of startup, shutdown, and malfunction.

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State implementation plans ("SIPs") developed under the CAA typically exclude periods of startup, shutdowns, and malfunctions, but the EPA has proposed a rule to eliminate such exclusions. The proposed rule will likely be final in 2015, after which the states must modify their implementation plans by 2017. These new requirements could reduce flexibility and increase operational costs for TVA’s coal-fired plants.

Clean Power Plan. On June 2, 2014, the EPA issued proposed carbon pollution standards for existing power plants, referred to as the “Clean Power Plan.”  The “Clean Power Plan” proposes state-specific emission rate goals to lower carbon dioxide ("CO₂") emissions from power plants, targeting a 30 percent nationwide reduction in CO₂ emissions from 2005 levels by 2030. Each state’s guideline is an output-based emissions rate (fossil CO₂ lbs/adjusted MWh) based on 2012 historical emissions and generation. The EPA identified four sets of measures or “building blocks” that are in use today by some states and utilities, and that together make up the best system of emission reduction ("BSER") for reducing carbon pollution: (1) heat rate improvements at coal-fired units, (2) increased dispatch of natural gas combined cycle units ("NGCCs"), (3) increased utilization of non-emitting resources, and (4) increased demand-side energy efficiency. Each state’s emission guideline is calculated by applying these four building blocks to 2012 historical fossil emissions and generation. The EPA is proposing an “interim goal” that a state must meet on average over the 10-year period from 2020-2029 and a “final goal” that a state must meet at the end of that period in 2030 and thereafter based on a three-year average. States must develop and submit plans to meet their goals and can comply individually or within a multi-state framework. States would be required to submit their plans to the EPA by June 30, 2016. The final form of these standards is uncertain. Comments on the proposed rule are due to the EPA by December 1, 2014, and the EPA expects to finalize the rule in June 2015.

Petition to Expand the Ozone Transport Region. On December 9, 2013, eight of the twelve states that make up the Ozone Transport Region ("OTR") submitted a petition to the EPA requesting that nine states, including Kentucky and Tennessee, be added to the OTR. TVA is unable to predict the outcome of the petition at this time. Should the petition be granted, additional controls may be required on existing electric generating units and other sources in the additional states. New and modified sources would have to have state of the art controls and meet other requirements as well.

Climate Change

Legislation. Although climate change legislation has failed to progress in the U.S. Congress in past years, there is continuing interest in legislation that could regulate GHG emissions or impose other energy-related restrictions and requirements. If legislation intended to limit GHG emissions or impose other energy policies were to become law, such limitations would likely affect TVA’s coal-fired plants and could affect other fossil fuel-fired plants. The costs and impacts or such regulation could be significant for TVA. There is no way to predict the likelihood or form of such legislation at this time.

Regulation. The Obama Administration has promulgated a number of regulations that impose limitations upon emissions of GHGs, including CO₂, from power plants. The most important of these apply to major new sources of GHGs, including coal-fired and gas-fired power plants, and major modifications of existing plants. On June 23, 2014, the U.S. Supreme Court affirmed and reversed parts of the regulation. The decision exempts a small proportion of facilities from the “prevention of serious deterioration” program but allows most major pollution sources, including power plants and refineries, to be included. The regulation is back before the D.C. Circuit.

The EPA proposed GHG New Source Performance Standards ("NSPS") for new power plants, and the proposed rules were published in the Federal Register on January 8, 2014. The proposed rulemaking sets GHG NSPS for new fossil fuel-fired electric generating units constructed in the United States. This proposal only applies to new sources, which are sources that “commence construction” after January 8, 2014. This action proposes a standard of performance for fossil fuel-fired boilers and integrated gasification combined cycle units that burn coal, petroleum coke, and other fossil fuels that is based in part on carbon capture and storage as the BSER. This standard also proposes a standard for natural gas-fired stationary combustion turbines based on modern, efficient natural gas combined cycle technology as BSER. The final form of these standards is uncertain.

Biomass CO₂ Emissions. The EPA has considered the greenhouse gas implications related to biomass use at stationary sources through several actions, including the development and review of the “Accounting Framework for Biogenic CO₂ Emissions from Stationary Sources,” issued in September 2011.  That study was reviewed by the EPA’s Science Advisory Board in 2011 and 2012, and the EPA continues to assess the framework and consider scientific analysis and technical input from stakeholders.  The EPA’s final accounting framework for biogenic carbon is expected to be finalized in the first quarter of 2015. On July 12, 2013, the D.C. Circuit vacated the EPA’s biomass deferral rule, holding that the EPA did not have the authority to temporarily delay regulating biogenic CO₂ for three years pending the completion of its study to determine whether biogenic CO₂ emissions contribute to increases in CO₂ levels in the atmosphere.  

Executive Orders. To strengthen the Administration's efforts to increase government-wide energy efficiency and sustainability and implement goals in the President’s June 2013 Climate Action Plan, a Presidential Memorandum was issued on December 5, 2013, directing the federal government to consume 20 percent of electricity from renewable sources by 2020, to the extent economically feasible and technically practicable.  The new renewable energy consumption goals are 10 percent by 2015, 15 percent by 2016, 17.5 percent by 2018, and 20 percent by 2020.  To date, TVA has achieved an agency renewable energy use rate of 9.4 percent, which exceeds the Energy Policy Act goal of 7.5 percent by 2013.  TVA uses renewable energy

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from improvements to hydroelectric facilities and other sources as low-cost ways to meet these renewable energy requirements.  TVA is on track to achieve the 2020 goal of 20 percent renewable energy use.

International Accords. International agreements and protocols have not been adopted by the United States; accordingly, they would not become binding upon TVA unless and until they are enacted into law.

Litigation. In addition to legislative activity, climate change issues have been the subject of a number of lawsuits, including lawsuits against TVA.

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. SeeItem 1, Business —Power Supply.

Physical Impacts of Climate Change. TVA manages the potential effects of climate change on its mission, programs, and operations within its environmental management processes. In June 2014, TVA issued an updated Statement on Climate Change Adaptation, and in accordance with Executive Order 13514, TVA prepared an updated Climate Change Adaptation Action Plan.

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 I, 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 units in its generation fleet, installing emission control equipment on certain of its coal-fired units, increasing its purchases of renewable energy, 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 rules, 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 CO₂ emissions.

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 it does not apply directly to TVA, does apply to TVA’s LPCs located in that state.  TVA's policy is to provide compliance assistance to any distributor of TVA power, and TVA is providing assistance to the four 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 ERS efforts to support the covered Mississippi LPCs. 

Legislation has been proposed in Congress in the past to establish a national renewable energy standard ("RES") that could require energy providers, including TVA, to rely more on renewable energy resources. Such legislation has not passed but could be passed in the future.

Water Quality Control Developments

Cooling Water Intake Structures. On May 19, 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 cooling water intake structures 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 cooling water intake structures 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 will be 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 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 in the 2020-2022 timeframe.

Hydrothermal Discharges. The EPA and many states are beginning 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

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that may have to be re-justified through new studies. 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. On June 7, 2013, the EPA proposed revisions to the effluent guidelines for the steam electric power generating industry. The rule proposal focuses on stricter limitations and additional treatment of wastewaters from ash handling, air pollution control systems, coal combustion residual leachate, and enhanced mercury air control systems. Wastewater streams from air pollution control systems contain pollutants such as metals, total suspended solids, chlorides, and nutrients, which have typically been treated in settling ponds. The EPA identified four preferred alternatives which include numerical limits for each option. Depending on the stringency of the final rule, TVA likely would have to install additional wastewater treatment systems at its coal-fired plants, substantially increasing TVA’s water pollution control costs. The EPA is required to finalize the rulemaking by September 2015.

Groundwater Contamination. Environmental groups and state regulatory agencies are increasing their attention on groundwater contamination associated with coal combustion residuals ("CCRs") management activities such as ash ponds.  Seven of TVA’s 10 coal-fired plants are in some level of state regulatory groundwater assessment.  Three of those plants (Colbert, Gallatin Fossil Plant ("Gallatin"), and Shawnee) have investigations beyond monitoring and reporting.  Four of the seven TVA coal-fired plants (Gallatin, Shawnee, Johnsonville, and Widows Creek) have either underground storage tank groundwater monitoring, or groundwater remediation monitoring with state regulatory involvement.  As a result of these assessments and increased attention, TVA may have to change how it manages CCRs at some of its plants with associated increases in cost. These costs are not expected to be significant. In addition, TVA’s Environmental Research Center facility at Muscle Shoals, Alabama has an active groundwater monitoring program as part of a Resource Conservation and Recovery Act ("RCRA") Corrective Action Permit.

General 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 herbicide discharges. In addition, other new environmental regulations related to mountain top mining of coal in the Appalachian region under the Clean Water Act may increase the cost of coal that TVA purchases for its plants.

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 oil spills and other contamination that TVA is addressing. At September 30, 2014, TVA’s estimated liability for cleanup and similar environmental work for those sites for which sufficient information is available to develop a cost estimate is approximately $15 million and is included in Accounts payable and accrued liabilities and Other long-term liabilities on the Balance Sheet.

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 21 — Contingencies — Environmental Matters.

Coal Combustion Residuals. In May 2010, the EPA released the text of a proposed rule describing two possible regulatory options it is considering under RCRA for the disposal of CCRs generated from the combustion of coal by electric utilities and independent power producers. Under one option, CCRs would be regulated as a solid or special waste. Under the other option, CCRs would be regulated as a hazardous waste. Under either option, the EPA or the state would regulate the construction of impoundments and landfills, and seek to ensure both the physical and environmental integrity of disposal facilities. CCRs include fly ash, bottom ash, boiler slag, and flue gas desulfurization materials. If the EPA decides to regulate CCRs as hazardous, the beneficial use of CCRs now sold by TVA and other utilities likely would be impacted, and this could result in requirements to remediate existing CCR management facilities at a substantial cost. The EPA has not announced which regulatory option it will take with respect to the management and disposal of CCRs. TVA is therefore unable to determine the effects of this proposed rule at this time. In April 2012, several environmental organizations filed suit against the EPA to compel the EPA to take action on the proposed rule. TVA cannot predict the outcome of this litigation.

Kingston Ash Spill. See Note 10 for a discussion of the environmental issues associated with the Kingston ash spill.

Environmental Investments

From the 1970's to 2014, TVA spent approximately $5.9 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.

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SO₂ Emissions and NO_x Emissions. To reduce SO₂ emissions, TVA installed scrubbers on 17 coal-fired units with scrubbers under construction on four more units, and switched to lower-sulfur coal at 24 coal-fired units. To reduce NO_X emissions, TVA installed SCRs on 20 coal-fired units with SCRs under construction on four more units, operates selective non-catalytic reduction systems ("SNCR") on four units, installed low-NO_X burners or low-NO_X combustion systems on 25 units, optimized combustion on 5 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 or announced plans to retire 32 of 59 coal-fired units and expects all coal-fired units will either have scrubbers and SCRs, be repowered to renewable biomass, or be retired. See Power Supply— Coal-Fired.

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.

Primarily due to the actions described above, emissions of NO_x and SO₂ on the TVA system have been reduced by 91 percent below peak 1995 levels and by 95 percent below 1977 levels, respectively. These controls also have provided a cobenefit of reducing hazardous air pollutants, including mercury, at some units. For CY 2013, TVA’s emission of CO₂ from its sources was 72 million tons, a 32 percent reduction from 2005 levels. To remain consistent and provide clear information and to align with the EPA’s reporting requirements, TVA will continue to report CO₂ emissions on a CY basis.

There could be additional material costs if reductions of GHGs, including CO₂, 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. A number of emerging EPA regulations establishing more stringent air, water, and waste requirements could result in significant changes in the structure of the U.S. power industry, especially in the eastern half of the country.

TVA currently anticipates spending significant amounts on environmental projects through 2025 including investments in new clean energy generation including natural gas, nuclear, and renewables to reduce TVA's overall environmental footprint.  Based on options for certain coal-fired units under the Environmental Agreements and the anticipated results of updates to its IRP in 2015, the amount and timing of expenditures could change.  See Power Supply— Coal-Fired and Estimated Required Environmental Expenditures below.

Estimated Required Environmental Expenditures

The following table contains information about TVA’s current estimates on projects related to environmental laws and regulations.

Air, Water, and Waste Quality Estimated Potential Environmental Expenditures(1) At September 30, 2014 (in millions)
	Estimated Timetable	Total Estimated Expenditures
Site environmental remediation costs(2)	2015+	$	15
Coal combustion residual conversion and remediation(3)	2015-2029	1,400
Proposed clean air control projects(4)	2015-2025	900
Clean Water Act requirements(5)	2015-2023	400

Notes

(1) These estimates are subject to change as additional information becomes available and as regulations change.

(2)  Estimated liability for cleanup and similar environmental work for those sites for which sufficient information is available to develop a cost estimate.

(3)  Includes closure of impoundments, construction of lined landfills, and construction of dewatering systems.

(4)  Includes air quality projects that TVA is currently planning to undertake to comply with existing and proposed air quality regulations, but does not include any

projects that may be required to comply with potential GHG regulations or transmission upgrades.

(5)  Includes projects that TVA is currently planning to comply with revised rules under the Clean Water Act (i.e., Section 316(b) and effluent limitation guidelines for

steam electric power plants).

Employees

On September 30, 2014, TVA had 11,542 employees, of whom 4,255 were trades and labor employees.  On October 1, 2014, TVA had 11,260 employees, of whom 4,170 were trades and labor employees.  This change reflects, in part, departures of employees impacted by TVA’s 2014 restructuring and having a September 30, 2014 separation date.  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 dealing 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.

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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.  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, Congress may enact legislation that expands or reduces TVA's activities, changes its governance structure, requires TVA to sell some or all of the assets that it operates, reduces or eliminates the United States's ownership of TVA, or even liquidates TVA. Additionally, Congress could act, or fail to take action, on various issues which 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.

TVA may become subject to additional environmental regulation.

New environmental laws, regulations, and orders may become applicable to TVA or the facilities it operates, and existing environmental regulations may be revised or reinterpreted in a way that adversely affects TVA.  Possible areas of future regulation include, but are not limited to, the following:

Greenhouse gases.  Costs to comply with future regulation of CO₂ and other GHGs may negatively impact TVA's cash flows, financial position, and results of operations.  The cost impact of legislation or regulation cannot be determined at this time.

Coal combustion residuals.  The federal government has proposed stronger regulations concerning CCRs, and state governments may impose additional regulations.  These regulations may require TVA to make additional capital expenditures, increase operating and maintenance costs, or even cause it to shut down certain facilities. TVA currently expects to spend between $1.5 billion and $2.0 billion to convert its wet coal ash and gypsum facilities to dry storage collection facilities.  Changes to the regulations, among other things, could cause actual costs to exceed expected costs.

Renewable energy portfolio standards.  TVA is not currently obligated to provide a percentage of the power it sells from renewable sources but may be required to do so in the future.  Such developments could require TVA to make significant capital expenditures, increase its purchased power costs, or make changes in how it operates its facilities.

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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. For example, should the United States approach the national debt ceiling, the United States Treasury might, as part of an effort to control federal spending, attempt to require TVA to receive approval before TVA disburses funds. Additionally, the Office of Management and Budget might, in the event that automatic spending cuts go into effect, attempt to require TVA to reduce its budget by a specified percentage. Such attempts to restrict TVA's ability to control or allocate funds could adversely affect its cash flows, results of operations, and financial condition, its relationships with 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 by the fence and protected by the anti-cherrypicking provision.  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 Congressional legislation at some time in the future. If Congress 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 become subject to outside review, there could be material adverse effects on TVA including, but not limited to, the following:

The TVA Board might be unable to set rates at a level sufficient to generate adequate revenues to service TVA's financial obligations, properly operate and maintain its power assets, and provide for reinvestment in its power program; and

TVA might become subject to additional regulatory oversight that could impede its ability to manage its business.

TVA may lose responsibility for managing the Tennessee River system.

TVA's management of the Tennessee River system is important to effectively operate the 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.

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.

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, nuclear, and transmission reliability areas.  To settle the EPA and other claims involving alleged NSR violations, TVA agreed to retire 18 coal-fired units and pay a civil penalty.  The cost to install the necessary equipment to comply with existing environmental laws, regulations, settlement agreements, and orders at some other facilities may render some facilities uneconomical, which may cause TVA to retire or idle additional facilities.  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.

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Additional NRC requirements may negatively affect TVA's cash flows, results of operations, and financial condition or impact TVA's ability to operate its nuclear facilities.

In response to concerns raised by the Fukushima events, the NRC has required TVA, along with other utilities that operate nuclear facilities, to make substantial modifications at its nuclear facilities. Additionally, the NRC is requiring TVA to evaluate certain of its hydro and nuclear facilities to prevent damage to the nuclear facilities in the event of a catastrophic flood event. Complying with these requirements will require significant capital expenditures and may negatively affect TVA's cash flows, results of operations, financial condition, and reputation. Should TVA be unable to comply with the requirements, TVA may not be able to operate its nuclear facilities as currently contemplated by TVA's generation plans.

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 other legal proceedings in the future in the ordinary course of business, as a result of catastrophic events or otherwise.  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 and may require TVA to reduce emissions from its coal-fired units, including emissions of GHGs, to a greater extent than TVA had planned.

TVA may be responsible for environmental clean-up activities.

TVA may be responsible for on-site liabilities associated with the environmental condition of facilities or property that TVA has acquired or that TVA operates regardless of when the liabilities arose, whether they are known or unknown, and whether they were caused by TVA, prior owners or operators, or a third party. TVA may also be responsible for off-site liabilities associated with the off-site disposal of waste materials containing hazardous substances or hazardous wastes.

TVA is largely restricted to a defined service area.

If demand for power in TVA's service area decreases, TVA's ability to expand its customer base would be constrained by its inability to pursue new customers outside its service area. Accordingly, the reduction in demand would 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.

OPERATIONAL RISKS

TVA may incur delays and additional costs in power plant construction and may be unable to obtain necessary regulatory approval.

TVA is completing the construction of Watts Bar Unit 2, constructing two natural gas-fired plants, preserving Bellefonte Unit 1 for possible future completion, scheduling major upgrades to and modernization of current generating plants, and evaluating construction of more generating facilities in the future.  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 regulations, lack of productivity, human error, and the failure to schedule activities properly.  In addition, if TVA does not obtain the necessary regulatory approvals or licenses, is otherwise unable to complete the development or construction of a facility, decides to cancel construction of a facility, or incurs delays or cost overruns in connection with constructing a facility, TVA's cash flows, financial condition, and results of operations could be negatively affected.  Further, if construction 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.

TVA has been experiencing issues with certain of its nuclear power units, including some issues that the NRC has considered to be of high significance. If these issues continue or if TVA is unable to correct the problems, TVA might voluntarily shut down one or more units or be ordered to do so by the NRC. In either case, placing the unit(s) back into operation could be a lengthy and expensive process, and TVA's cash flows, results of operations, financial condition,

and reputation may be negatively affected.

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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 six operating nuclear units and has resumed construction of Watts Bar Unit 2, which TVA anticipates will be placed in service in CY 2015.  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. Any nuclear incident in the United States, even at a facility that is not operated by or licensed to TVA, has the potential to impact TVA adversely by obligating TVA to pay up to $114 million per year and a total of $764 million per nuclear incident under the Price-Anderson Act and otherwise 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, Congress 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 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, as it did during the 2008-2009 recession, 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.  If the NRC modifies existing requirements or adopts new requirements, 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.

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TVA’s facilities and information infrastructure may not operate as planned due to physical and cyber threats to TVA’s security.

TVA has an extensive generation and transmission system and supporting infrastructure that includes both physical and cyber assets. Potential targets include, among other things, TVA’s generation facilities, transmission infrastructure such as substations and towers, information technology systems, and network 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 or cyber attacks.

Physical Attacks. TVA’s operations are located over wide areas and are protected by automated monitoring systems, local law enforcement, TVA employees, or a combination thereof. However, it may not be possible to effectively deter or prevent attacks, including vandalism and more significant acts, at all TVA facilities. 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.

Cyber Attacks. TVA's operations are extensively computerized, so a failure or breach of its information technology assets, whether caused by a cyber attack or otherwise, may significantly disrupt operations, including the generation and transmission of electricity, negatively affect TVA's cash flows, results of operations, and financial condition, pose health and safety risks, and result in the compromise of sensitive data. The theft, damage, or improper disclosure of sensitive data may also subject TVA to penalties and claims from third parties.

TVA's generation and transmission assets or their supporting infrastructure may not operate as planned.

Many of TVA's generation and transmission assets and their supporting infrastructure have been operated more often, or for more prolonged periods, than originally intended. Many of TVA's coal-fired units, for example, have been operating since the 1950s and have been in nearly constant service since they were completed. Additionally, certain of TVA's newer assets have experienced operating issues and manufacturing defects in essential equipment. If TVA's generation and transmission 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; and

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

In addition, the failure of TVA's generation and transmission assets or their supporting infrastructure 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 failure of a containment pond, or an incident at a coal-fired, gas-fired, or nuclear facility.  Any of these potential outcomes may negatively affect TVA's cash flows, results of operations, financial condition, and reputation.

TVA’s safety program 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

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regulatory scrutiny, damage its reputation, interfere with its ability to attract or retain a skilled workforce, and 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 reduce river levels and 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.

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, droughts, floods, tornadoes, wars, national emergencies, terrorist activities, pandemics, and 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 costs to construct nuclear units significantly increase or if public opposition to nuclear power makes operating such plants less feasible as a result of any of these events, TVA may be forced to forego any future construction at its nuclear facilities or shut them down.  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.

TVA purchases coal, uranium, natural gas, fuel oil, and electricity from a number of suppliers.  Additionally, TVA purchases other items, such as anhydrous ammonia, liquid oxygen, or replacement parts that are critical to the operation of certain generation assets. Disruption in the acquisition or delivery of fuel, purchased power, or other critical supplies may result from a variety of physical and commercial events, political developments, 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 adversely 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 which affect the supply of water in the Tennessee River system and Cumberland River system 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

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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.  An inadequate supply of 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, and incidents affecting bodies of water not managed by TVA.  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 U.S. Army Corps of Engineers operates and manages other bodies of water upon which some of TVA's facilities rely.  Events at these bodies of water or their associated hydroelectric facilities may interfere with the flow of water and may result in TVA's having insufficient water to meet the needs of its plants.  If TVA has insufficient water to meet the needs of its plants, TVA may be required to reduce generation at its affected facilities to levels compatible with the available supply of water.

TVA's determination of the appropriate mix of generation assets may change.

TVA has determined that its power generation assets should consist of a mixture 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, the forecasted demand for electricity, and the expense of adding air pollution controls to its coal-fired units. If any of these assumptions materially change or are overtaken by subsequent events, then TVA's generation mix may not adequately address its operational needs. 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. Additionally, TVA is taking measures to maintain flexibility by keeping certain facilities and sites available as generation options. There are costs associated with maintaining these options that could impact TVA's flows, results of operation, financial condition, and reputation.

FINANCIAL, ECONOMIC, AND MARKET RISKS

TVA’s cost reduction efforts may not be successful.

TVA has been working to reduce operating expenses to offset reductions in power demand.  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 pension plans.

At September 30, 2014, TVA's qualified pension plan had assets of $7.5 billion compared to liabilities of $12.2 billion.  The qualified plan is mature with approximately 23,400 retirees and beneficiaries receiving benefits of approximately $650 million per year. The costs of providing pension benefits depend upon a number of factors, including, but not limited to: provisions of the pension plans; changing employee demographics; rates of increase in compensation levels; rates of return on plan assets; discount rates used in determining future benefit obligations and required funding levels; future government regulation; and levels of contributions made to the plans.

Any of these factors or any number of these factors could keep at high levels, or even increase, the costs of providing pension benefits and require TVA to make significant contributions to the pension plans.  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 plans. Additional contributions to the plans and absorption of additional costs would negatively affect TVA's cash flows, results of operations, and financial condition.

Approaching or reaching TVA's debt ceiling could limit TVA's ability to carry out its business.  Additionally, TVA's debt ceiling could be made more restrictive.

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, 2014, TVA had $23.6 billion of Bonds outstanding (not including noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million).

Approaching or reaching the debt ceiling may adversely affect TVA's business by limiting TVA's ability to access capital markets and increasing the amount of debt TVA must service.  Also, Congress 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 maintain power program assets, to construct additional generation facilities, 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 credit rating actions.

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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 alternative 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 that TVA, unlike many 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 United States'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 United States. 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 United States, TVA, as a corporate agency and instrumentality of the United States, may be impacted if the sovereign credit ratings of the United States are downgraded. For example, in August 2011, one rating agency lowered its long-term rating on the United States and then lowered TVA's rating based on the application of the rating agency's government-related entities criteria. An additional or further downgrade of the United States'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.

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 may have the following effects:

A downgrade could increase TVA's interest expense by increasing the interest rates that TVA pays on new Bonds that it issues.  An increase in TVA's interest expense 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 result in TVA's having to post collateral under certain physical and financial contracts that contain rating triggers.

A downgrade below a contractual threshold may prevent TVA from borrowing under three credit facilities totaling $2.5 billion or posting letters of credit as collateral under these facilities. At September 30, 2014, there were $1.0 billion of letters of credit outstanding under these facilities. If TVA were no longer able to post letters of credit as collateral, TVA's liquidity would be negatively affected, for TVA would likely have to post cash as collateral instead of letters of credit.

A downgrade may lower the price of TVA securities in the secondary market, thereby hurting investors who sell TVA securities after the downgrade and diminishing the attractiveness and marketability of TVA securities.

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 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 be significantly reduced, negatively affecting TVA's cash flows, results of operations, and financial condition.

Some of the factors that could reduce the demand for electricity include, but are not limited to, the following:

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Economic downturns.  Renewed economic downturns in TVA's service area or other parts of the United States could reduce overall demand for power and thus reduce TVA's power sales and cash flows, especially if TVA's industrial customers reduce their operations and thus their consumption of power.

Loss of customers.  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, expecially because of the difficulty in replacing customers on account of the fence.

Change in technology.  Research and development activities are ongoing to improve existing and alternative technologies to produce electricity, including gas turbines, wind turbines, fuel cells, microturbines, solar cells, and distributed generation devices.  It is possible that advances in these or other alternative technologies could reduce the costs of electricity production from alternative technologies to a level that will enable these technologies to compete effectively with traditional power plants like TVA's.  To the extent these technologies become a more cost-effective option for certain customers, TVA's sales to these customers could be reduced, negatively affecting TVA's cash flows, results of operations, and financial condition.

Increased Energy Efficiency and Conservation.  Increasingly efficient use of energy as well as conservation efforts may reduce the demand for power. Such a reduction could have a significant impact on TVA, especially if it occurs during an economic downturn or a period of slow economic growth, could negatively affect TVA's cash flows, results of operations, and financial condition, and could result in higher rates and changes to how TVA operates.

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.  If prices of commodities critical to operations, including coal, uranium, natural gas, fuel oil, crude oil, construction materials, emission allowances, and electricity, increase, TVA's rates may increase.

Investment Price Risk.  TVA is exposed to investment price risk in the NDT, its Asset Retirement Trust ("ART"), its Supplemental Executive Retirement Plan ("SERP"), its Long-Term Deferred Compensation Plan ("LTDCP"), and its 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 LTDCP 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, the ART, and TVA's pension fund, 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, 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 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.  The value of the U.S. dollar compared with other currencies has fluctuated widely in recent years, and, if not effectively managed, foreign currency exposure could negatively impact TVA's cash flows, results of operations, and financial condition.

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.

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The market for TVA securities 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 securities.  However, the underwriters and dealers are not obligated to make a market in any TVA securities and may terminate any market-making activities at any time without notice.

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'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 United States.

Although TVA is a corporate agency and instrumentality of the United States government, TVA securities are not backed by the full faith and credit of the United States.  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.  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.

GENERAL BUSINESS RISKS

TVA's organizational transformation efforts may not be successful.

TVA has been working to improve its corporate culture.  The failure to achieve or maintain improvements in TVA’s corporate culture may contribute to the likelihood of incidents such as significant environmental events, delays in construction projects, or other 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.

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, significant delays in construction projects, acts or omissions of TVA management, 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 imposition of additional laws and regulations that negatively affect the way TVA conducts its business.

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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 such as Watts Bar Unit 2, and successfully implement its organizational transformation efforts.

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. Appointment of a member of the TVA Board requires confirmation by the U.S. Senate following appointment by the President. Further, TVA Board members may not continue in office indefinitely until a successor is appointed. 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.

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 United States of America.  TVA may acquire real property as an agent of the United States by negotiated purchase or by eminent domain.

Generating Properties

At September 30, 2014, TVA-operated generating assets consisted of 41 active coal-fired units and 18 inactive coal-fired units, 6 nuclear units, 109 conventional hydroelectric units, four pumped-storage units, 11 combined-cycle power blocks,87 simple-cycle units, 5 diesel generator units, one wind energy site (out of service), and 16 solarsites.  In addition, TVA has biomass co-firing potential at its coal-fired sites. See Item 1, Business — Power Supply — Net Capability for a table that indicates the location, capability, and in-service dates for certain of these properties, which chart is incorporated by reference into this Item 2, Properties.  As of September 30, 2014, 24 of the simple-cycle combustion turbine units were leased to private entities and leased back to TVA under long-term leases. In addition, TVA is leasing the three Caledonia combined-cycle power blocks under a long-term lease. TVA is in the process of constructing additional generating assets. For a discussion of these assets, see Item 1, Business —Cleaner Energy Initiatives.

Transmission Properties

TVA’s transmission system interconnects with systems of surrounding utilities and consists primarily of the following assets:

• Approximately 2,500 circuit miles of 500 kilovolt, 11,500 circuit miles of 161 kilovolt, and 2,200 circuit miles of other voltage transmission lines;

• 511 transmission substations, power switchyards, and switching stations; and

• 1,278 customer connection points (customer, generation, and interconnection).

At September 30, 2014, 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.

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).

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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 throughout its service area in addition to the buildings located at its generation and transmission facilities, including office buildings, customer service centers, power service centers, warehouses, visitor centers, and crew quarters.  The most significant of these buildings are the Knoxville Office Complex and the Chattanooga Office Complex.  TVA also has a significant number of buildings in Muscle Shoals, Alabama, and is implementing strategies to further reduce its Muscle Shoals real property holdings.

Disposal of Property

Under the TVA Act, TVA has broad authority to dispose of personal property but only limited authority to dispose of real property.  The primary, but not exclusive, sources of TVA's authority to dispose of real property are briefly described below:

• Under Section 31 of the TVA Act, TVA has authority to dispose of surplus real property at a public auction.

• Under Section 4(k) of the TVA Act, TVA can 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 and to grant easements and rights-of-way upon which are located transmission or distribution lines.

• Under Section 15d(g) of the TVA Act, TVA can dispose of real property in connection with the construction of generating plants or other facilities under certain circumstances.

Additionally, under 40 U.S.C. § 1314, 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.

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 21 — Legal Proceedings, which discussion is incorporated by reference into this Item 3.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

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PART II

ITEM 5.  MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Not applicable.

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ITEM 6.  SELECTED FINANCIAL DATA

The following selected financial data for the years 2010 through 2014 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 2010, 2011, and 2012 financial statement presentations to conform to the 2013 and 2014 presentations.

Selected Financial Data(1)(2) For the years ended, or at, September 30 (dollars in millions)
	2014		2013		2012		2011		2010
Sales (millions of kWh)	158,057		161,925		165,255		167,730		173,662
Peak load (MW)	33,352		28,726		31,098		31,434		31,778
Operating revenues	$	11,137	$	10,956	$	11,220	$	11,841	$	10,874
Fuel expense	$	2,730	$	2,820	$	2,680	$	2,926	$	2,092
Purchased power expense	$	1,094	$	1,027	$	1,189	$	1,427	$	1,127
Operating and maintenance expense	$	3,341	$	3,428	$	3,510	$	3,617	$	3,232
Net interest expense	$	1,169	$	1,226	$	1,273	$	1,305	$	1,294
Net income	$	469	$	271	$	60	$	162	$	972
Construction expenditures	$	2,384	$	2,051	$	2,119	$	2,417	$	2,015
Total assets	$	45,596	$	46,106	$	47,334	$	46,393	$	42,753
Financial obligations
Long-term debt, net(3)
Long-term power bonds, net	$	21,948	$	22,315	$	20,269	$	22,412	$	22,389
Long-term debt of variable interest entities	$	1,279	$	1,311	$	981	$	—	$	—
Total long-term debt, net	$	23,227	$	23,626	$	21,250	$	22,412	$	22,389
Current debt, net(3)
Short-term debt, net	$	596	$	2,432	$	1,507	$	482	$	27
Current maturities of power bonds	$	1,032	$	32	$	2,308	$	1,537	$	1,008
Current maturities of long-term debt of variable interest entities	$	32	$	30	$	13	$	—	$	—
Total short-term debt, net	$	1,660	$	2,494	$	3,828	$	2,019	$	1,035
Total debt(3)	$	24,887	$	26,120	$	25,078	$	24,431	$	23,424
Capital leases(4)	$	109	$	43	$	35	$	5	$	47
Membership interests of variable interest entity subject to mandatory redemption(4)	$	39	$	40	$	—	$	—	$	—
Leaseback obligations	$	691	$	761	$	1,203	$	1,282	$	1,353
Energy prepayment obligations	$	410	$	510	$	612	$	717	$	822

Notes

(1)  See Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations for a description of certain items in 2014, 2013, and 2012

affecting results in those years.

(2)  See Item 1A, Risk Factors and Note 21 for a discussion of risks and contingencies that could affect TVA’s future financial results.

(3)  See Note 9, Note 11 — Membership Interests of VIE Subject to Mandatory Redemption and Note 13— Debt Outstanding.

(4)  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, 2014 (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 2014;

• 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 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, 2014, TVA provided electricity to approximately 52 large industrial customers, six federal agency customers, and 155local power company customers of TVA ("LPCs") that serve over nine million people in parts of seven southeastern states.  TVA generates virtually all of its revenues from the sale of electricity, and in 2014 revenues from the sale of electricity totaled $11.0 billion.  As a wholly-owned agency and instrumentality of the United States, however, TVA differs from other electric utilities in a number of ways:

1. TVA is a government corporation.

2. The area in which TVA sells power is limited by the Tennessee Valley Authority Act of 1933, as amended (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.

3. 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.

4. 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 ("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.

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TVA's Mission of Service

TVA was built for the people, created by Congress, 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 - Provide reliable, affordable electric power throughout the Tennessee Valley.

• Environment - Act as steward of the region’s natural resources.

• Economic Development - Serve as a catalyst for sustainable economic development.

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, the need to modernize its generating fleet, and changing customer needs. To adapt to these challenges, TVA has developed the following strategic imperatives to position itself to carry out its mission of serving the people of the Tennessee Valley:

• Rates - Maintain low rates.

• Stewardship - Be responsible stewards.

• Debt - Live within its means.

• Asset Portfolio - Meet reliability expectations and provide a balanced portfolio.

TVA is currently updating its 2011 Integrated Resource Plan ("IRP") which recommended a planning direction consistent with TVA's Environmental Policy and supported TVA's renewed vision of meeting its customers’ power needs while addressing the substantial challenges facing the electric utility industry. It is anticipated that the recommended planning direction in the updated IRP will continue to provide flexibility to make sound choices as economic and regulatory changes occur. Resource recommendations in the updated IRP are expected to balance costs, energy efficiency, system reliability, and environmental responsibility for TVA’s stakeholders. The new IRP is expected to be published in 2015.

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.

Linking the Mission to Performance

TVA has formulated six key performance measures to support its strategic imperatives. Changes in TVA’s corporate performance measures from 2013 to 2014 reflect TVA's commitment to its mission by adding a measure of system reliability to support customer service and a measure of reportable environmental events in support of its goal of being a responsible steward of assets supporting its mission. The 2014 results compared with targets for these key indicators are reflected in the following chart.

Corporate Measure	Weight	Actual	Threshold	Target	Stretch
Corporate total spend ($ millions)	40%	$837	$905	$884	$864
Nuclear operating availability factor (OAF) (%)	20%	96.7%	96.1%	97.0%	97.9%
Coal seasonal equivalent forced outage rate (%)	15%	5.4%	6.3%	5.1%	3.2%
Load not served (system minutes)	10%	4.0	7.8	5.3	3.1
Reportable environmental events (REEs)	10%	10	21	17	12
Combined cycle seasonal equivalent forced outage rate (%)	5%	1.1%	4.0%	2.7%	1.4%

Executive Overview

Demand for electricity was influenced by several factors during 2014. Sales to LPCs increased slightly for the year ended September 30, 2014, as compared to the year ended September 30, 2013, primarily due to an extremely cold winter in 2014. Sales also increased due to a slight growth in economic activity in the TVA service area during the same period. The

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increase in 2014 sales was offset by decreased demand from United States Enrichment Corporation ("USEC"), which began ceasing operations in May 2013.

TVA’s net income for the years ended September 30, 2014 and 2013, was $469 million and $271 million, respectively. Base revenue increased $208 million for the year ended September 30, 2014, as compared to the prior year primarily due to higher sales to LPCs and the non-fuel base rate increase that became effective on October 1, 2013.  Operating and maintenance costs decreased $87 million for the year ended September 30, 2014, as compared to the prior year primarily due to cost savings initiatives undertaken by management.  These positive results were partially offset by an increase in depreciation expense related to the timing of idling certain coal-fired units.  TVA continues to make operational changes to its generating fleet and to pursue cost reduction initiatives across all business units, with a goal of keeping its rates competitive.

During 2014, TVA focused on several operational areas including improving nuclear performance, prioritizing operating and maintenance expenditures, restoring and upgrading assets, executing the Watts Bar Nuclear Plant ("Watts Bar") Unit 2 construction program, implementing organizational restructuring, and finalizing asset decisions. With improvements at its Browns Ferry Nuclear Plant ("Browns Ferry"), the Nuclear Regulatory Commission ("NRC") has reported that oversight for TVA's six nuclear units is now at baseline levels. Watts Bar Unit 2 continues to be on schedule and on budget for commercial operation by December 2015. TVA’s restructuring and other measures, including assessments of its generating assets, have resulted in reduced operating and maintenance expenses, which should position TVA to be more competitive in future years. TVA made a strategic decision to use cash on hand to reduce debt by $1.2 billion and fulfill some of its near-term capital funding needs rather than issuing additional debt. Additionally, TVA’s economic development efforts continue to position TVA as a national leader in the categories of total new jobs created and total capital investment associated with that job creation.

Longer-term, TVA plans to make sound investments in a diversified, cleaner portfolio to provide electricity at the lowest feasible rate while meeting operational challenges including generation reliability, changing regulatory requirements, Watts Bar Unit 2 licensing and dual operations, fuel cost uncertainties, project management and milestones, and transmission system considerations. See Liquidity and Capital Resources and Key Initiatives and Challenges below.

Results of Operations

Sales of Electricity

Sales of electricity accounted for virtually all of TVA's operating revenues in 2014, 2013, and 2012. TVA sells power at wholesale rates to LPCs that 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 that exceeds the needs of the TVA system is sold under exchange power arrangements with certain other power systems.

The following table compares TVA’s energy sales statistics for the years ended September 30, 2014, 2013, and 2012:

Sales of Electricity For the years ended September 30 (millions of kWh)
	2014	Percent Change		2013	Percent Change		2012
Local power companies	137,772	4.3	%	132,154	0.2	%	131,885
Industries directly served	17,417	(33.1	)%	26,016	(14.6	)%	30,446
Federal agencies and other	2,868	(23.6	)%	3,755	28.4	%	2,924
Total sales of electricity	158,057	(2.4	)%	161,925	(2.0	)%	165,255

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Weather affects both the demand for TVA power and the price for that power. TVA uses degree days to measure the impact of weather on its power operations. Degree days measure the extent to which average temperatures in the five largest cities in TVA's service area vary from 65 degrees Fahrenheit.

2014 Compared to 2013

Degree Days
	2014	Normal(1)	Percent Variation		2013	Normal(1)	Percent Variation		2014	2013	Percent Change
Heating Degree Days	3,699	3,360	10.1	%	3,333	3,360	(0.8	)%	3,699	3,333	11.0	%
Cooling Degree Days	1,898	1,863	1.9	%	1,762	1,863	(5.4	)%	1,898	1,762	7.7	%
Total Degree Days	5,597	5,223	7.2	%	5,095	5,223	(2.5	)%	5,597	5,095	9.9	%

Note

(1)  This calculation is updated every five years in order to incorporate the then most recent 30 years. It was last updated in 2011.

Sales of electricity decreased 3.9 billion kilowatt hours ("kWh") for the year ended September 30, 2014, compared to the year ended September 30, 2013, primarily due to a decrease in demand from industries directly served. The reduced demand was largely the result of a decrease in demand by USEC, which began ceasing operations during the third quarter of 2013. Partially offsetting this decrease in sales to industries directly served was an increase in sales to LPCs due primarily to 11 percent more heating degree days and eight percent more cooling degree days than the prior year.

2013 Compared to 2012

Degree Days
	2013	Normal(1)	Percent Variation		2012	Normal(1)	Percent Variation		2013	2012	Percent Change
Heating Degree Days	3,333	3,360	(0.8	)%	2,598	3,381	(23.2	)%	3,333	2,598	28.3	%
Cooling Degree Days	1,762	1,863	(5.4	)%	2,116	1,863	13.6	%	1,762	2,116	(16.7	)%
Total Degree Days	5,095	5,223	(2.5	)%	4,714	5,244	(10.1	)%	5,095	4,714	8.1	%

Note

(1)  This calculation is updated every five years in order to incorporate the then most recent 30 years. It was last updated in 2011. The 2013 Normal Heating Degree days differ from 2012 due to the occurrence of a leap year in 2012.

Sales of electricity decreased 3.3 billion kWh for the year ended September 30, 2013, compared to the year ended September 30, 2012, primarily due to a decrease in demand from industries directly served. The reduced demand was largely the result of a decrease in demand by USEC, which began ceasing operations during the third quarter of 2013. Offsetting the decrease from industries directly served was an increase in sales to federal agencies and other due to an increase in off-system sales as TVA had excess generation available for resale.

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Financial Results

The following table compares operating results for 2014, 2013, and 2012:

Summary Consolidated Statements of Operations
	2014		2013		2012
Operating revenues	$	11,137	$	10,956	$	11,220
Operating expenses	9,548		9,503		9,920
Operating income	1,589		1,453		1,300
Other income, net	49		44		33
Net interest expense	1,169		1,226		1,273
Net income	$	469	$	271	$	60

Operating Revenues. Operating revenues for 2014, 2013, and 2012 consisted of the following:

Operating Revenues
	2014		Percent Change		2013		Percent Change		2012
Revenue from sales of electricity
Local power companies	$	10,062	6.3	%	$	9,463	(0.5	)%	$	9,506
Industries directly served	780		(34.9	)%	1,199		(16.9	)%	1,442
Federal agencies and other	157		(6.0	)%	167		21.0	%	138
Revenue from sales of electricity	10,999		1.6	%	10,829		(2.3	)%	11,086
Other revenue	138		8.7	%	127		(5.2	)%	134
Total operating revenues	$	11,137	1.7	%	$	10,956	(2.4	)%	$	11,220

In April 2011, TVA implemented a revised wholesale rate structure. The rate structure provides price signals intended to encourage LPCs and end-use customers to shift energy usage from high-cost generation periods to less expensive generation periods. Under the revised wholesale structure, weather can positively or negatively impact both volume and effective rates, while only volume was impacted under the former wholesale structure. This is because the wholesale structure includes two components: a demand charge and an energy charge. The demand charge is based on the customer's peak monthly usage and increases as the peak increases. The energy charge is based on the kWhs used by the customer. In conjunction with the change, the rate structure was also revised to establish 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 tax equivalents associated with the fuel cost adjustments.

The changes in revenue components are summarized below:

	Variance 2014 vs. 2013			Variance 2013 vs. 2012
Fuel cost recovery	$	(19	)	$	(55	)
Base revenue	208			(230		)
Off-system sales	(19		)	28
Other revenue	11			(7		)
Total	$	181		$	(264	)

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2014 Compared to 2013

Operating revenues increased $181 million for the year ended September 30, 2014, compared to the year ended September 30, 2013, primarily due to a $208 million increase in base revenue. The increase in base revenue was attributable to higher sales volume to LPCs and the non-fuel base rate increase that became effective October 1, 2013. This was partially offset by a $19 million decrease in fuel cost recovery which resulted from the decrease in sales to industries directly served due to the reduction in demand by USEC. The decrease in fuel cost recovery primarily resulted from the decrease in sales to industries directly served due to the reduction in demand by USEC. In addition, off-system sales decreased by $19 million primarily due to a reduction in excess generating capacity.

2013 Compared to 2012

Operating revenues decreased $264 million for the year ended September 30, 2013, compared to the year ended September 30, 2012. The change was primarily due to a $230 million decrease in base revenue and a $55 million decrease in fuel cost recovery. The decrease in base revenue was attributable to a decrease in the effective base rate and lower sales of electricity.  The decrease in fuel cost recovery primarily resulted from the decrease in sales to industries directly served due

to the reduction in demand by USEC. Partially offsetting these decreases was an increase in off-system sales as a result of additional excess generating capacity.

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

Operating Expenses. Operating expenses for 2014,2013, and 2012 consisted of the following:

Operating Expenses For the years ended September 30
	2014		Percent Change		2013		Percent Change		2012
Fuel	$	2,730	(3.2	)%	$	2,820	5.2	%	$	2,680
Purchased power	1,094		6.5	%	1,027		(13.6	)%	1,189
Operating and maintenance	3,341		(2.5	)%	3,428		(2.3	)%	3,510
Depreciation and amortization	1,843		9.7	%	1,680		(12.5	)%	1,919
Tax equivalents	540		(1.5	)%	548		(11.9	)%	622
Total operating expenses	$	9,548	0.5	%	$	9,503	(4.2	)%	$	9,920

The following table summarizes TVA's net generation and purchased power in millions of kWh by generating source and the percentage of all electric power generated and purchased for the periods indicated:

Power Supply from TVA-Operated Generation Facilities and Purchased Power For the years ended September 30 (millions of kWh)
	2014			2013			2012
Coal-fired	62,525	39	%	62,519	38	%	58,584	34	%
Nuclear	53,778	33	%	52,100	32	%	55,244	33	%
Hydroelectric	13,228	8	%	18,178	11	%	12,817	8	%
Natural gas and/or oil-fired	12,615	8	%	13,102	8	%	16,650	10	%
Renewable resources (non-hydro)	5	—	%	9	—	%	25	—	%
Total TVA-operated generation facilities	142,151	88	%	145,908	89	%	143,320	85	%
Purchased power	18,740	12	%	18,848	11	%	25,294	15	%
Total power supply	160,891	100	%	164,756	100	%	168,614	100	%

2014 Compared to 2013

Fuel expense decreased $90 million for the year ended September 30, 2014, as compared to the prior year, primarily due to the timing of the fuel cost recovery mechanism and a reduction in sales volume. For the year ended September 30, 2014, the fuel cost recovery mechanism decreased fuel expense by $102 million as compared to the prior year, primarily due to the weather patterns in 2013. The fuel cost recovery mechanism provides a means to regularly adjust rates in order to reflect changing fuel and purchased power costs, including realized gains and losses relating to fuel commodity hedging transactions under TVA’s Financial Trading Program ("FTP"). See Note 15 — Derivatives Not Receiving Hedge Accounting Treatment —

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Derivatives Under 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 rates due to the operation of the fuel cost recovery mechanism. This difference is recorded as a regulatory asset or liability and represents over-collected revenues (regulatory liabilities) or under-collected revenues (regulatory assets). As a result of this treatment, eligible fuel expenses are correctly matched to the related revenue on the statements of operations. Additionally, a reduction in sales volume of two percent contributed to a $70 million decrease in fuel expense. Offsetting these decreases was an increase of $82 million in fuel expense primarily due to a change in the generation mix and higher natural gas prices.  Higher prices for natural gas increased fuel expense by approximately $50 million.  Decreased rainfall and runoff in 2014 contributed to a decrease of 27 percent in hydroelectric generation as compared to the prior year. Hydroelectric generation is TVA’s least expensive type of generation.  

Purchased power expense increased $67 million for the year ended September 30, 2014, as compared to the prior year, primarily due to an increase of 10 percent in the average price of purchased power. The increase in the average price resulted in a $104 million increase to purchased power expense and was largely a result of higher market prices for natural gas, as TVA’s primary source of purchased power is natural gas-fired generation. As an indication of general market conditions, the average Henry Hub natural gas spot price for the year ended September 30, 2014 was $4.348 per mmBtu, which was 20 percent higher than the average price for the prior year. Offsetting the increase in purchased power expense was a $31 million decrease due to the timing of the fuel cost recovery mechanism, primarily due to the weather patterns in 2013.

Operating and maintenance expense decreased $87 million in 2014 as compared with 2013. This decrease was primarily driven by a $122 million decrease in expenses related to cost savings initiatives undertaken by management (see Key Initiatives and Challenges — Cost Reduction Initiatives), a $52 million decrease in pension and post-retirement costs due to an increase in the discount rate, and a $25 million decrease in nuclear outage expense primarily due to a reduction in major outage projects. Offsetting these decreases were an increase of $65 million in employee-related expenses related to restructuring activities and a $42 million increase in other post-employment benefit expense.

Depreciation and amortization expense increased $163 million in 2014, compared to 2013, primarily due to an increase in the amount of accelerated depreciation recognized for certain coal-fired units to be idled. Incremental depreciation associated with the idling of coal-fired units was $206 million for the year ended September 30, 2014, compared with $49 million for the year ended September 30, 2013. See Note 1 — Property, Plant, Equipment, and Depreciation.

Tax equivalents expense decreased $8 million for the year ended September 30, 2014, as compared to the prior year. This change primarily reflects a decrease in gross revenue from power sales (excluding sales and deliveries to federal agencies and off-system sales with other utilities) during 2013, compared to 2012, as tax equivalent payments are calculated based on the previous year's results.

2013 Compared to 2012

Fuel expense increased $140 million for the year ended September 30, 2013, as compared to the prior year, primarily due to the utilization of more expensive generation resources. During 2013, TVA completed four nuclear refueling outages on units at Watts Bar, Browns Ferry, and Sequoyah Nuclear Plant ("Sequoyah"), which included a steam generator replacement project, compared to two nuclear refueling outages on units at Browns Ferry and Sequoyah during the prior year. This contributed to a six percent decrease in nuclear generation. A seven percent increase in coal-fired generation helped offset the decrease in nuclear generation and contributed to a $197 million increase in fuel expense due to the higher price of coal as compared to nuclear fuel.  While coal-fired generation contributed to the pricing variance, this was partially offset by a 39 percent increase in conventional hydroelectric generation, as a result of a 22 percent increase in rainfall and a 45 percent increase in runoff within the Upper Basin of the Tennessee Valley, and by a reduction in volume from lower sales of electricity of two percent, which decreased fuel expense by $57 million.

Purchased power expense decreased $162 million during the year ended September 30, 2013, as compared to the prior year, primarily due to a 25 percent decrease in the volume of power purchased. Higher market prices for natural gas contributed to the volume decrease, as TVA's primary source of purchased power is natural gas-fired generation. In addition, higher market prices for natural gas resulted in lower realized losses from TVA's financial trading program. Hydroelectric generation also helped to mitigate the need to purchase power to meet demand. Lower volume reduced purchased power expense by $303 million, but the higher market prices for the power that was purchased offset this reduction by $141 million.

Operating and maintenance expense decreased $82 million in 2013 as compared with 2012. The decrease was primarily attributable to a $66 million decrease in expenses related to coal-fired operations due to approximately 560 fewer outage days for coal-fired units compared with the prior year. In addition, scheduled maintenance expense decreased $58 million in 2013 as compared with 2012 in part due to the retirement or idling of less efficient units during 2012 and the first quarter of 2013. The decrease was also due to a $60 million decrease in costs related to post-employment benefits primarily due to the increase in the discount rate assumption used in the actuarial valuation of the liability related to workers’ compensation claims. These decreases were partially offset by a $99 million increase in nuclear expense related to an increase in the number of planned nuclear refueling outages and projects in 2013 as compared with the prior year.

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Depreciation and amortization expense decreased $239 million in 2013 as compared with 2012, primarily due to a decrease in the amount of accelerated depreciation recognized for certain coal-fired units to be idled. Incremental depreciation associated with the idling of coal-fired units was $49 million for the year ended September 30, 2013, compared with $308 million for the year ended September 30, 2012.

Tax equivalents expense decreased $74 million in 2013, compared to the same period of the prior year. This change primarily reflects a decrease in gross revenues from the sale of power (excluding sales or deliveries to other federal agencies and off-system sales with other utilities) during 2012 compared to 2011, as tax equivalent payments are calculated based on the previous year's results.

Interest Expense. Interest expense and interest rates for 2014, 2013, and 2012 were as follows:

Interest Expense and Rates For the years ended September 30
	2014			Percent Change		2013			Percent Change		2012
Interest expense(1)
Interest expense	$	1,344		(3.6	)%	$	1,394		(3.5	)%	$	1,444
Allowance for funds used during construction and nuclear fuel expenditures	(175		)	4.2	%	(168		)	(1.8	)%	(171		)
Net interest expense	$	1,169		(4.6	)%	$	1,226		(3.7	)%	$	1,273
	2014			Percent Change		2013			Percent Change		2012
Interest rates (average)
Long-term outstanding power bonds(2)	5.575		%	(2.6	)%	5.725		%	(2.3	)%	5.860		%
Long-term debt of VIE	4.601		%	(4.6	)%	4.824		%	(1.0	)%	4.874		%
Membership interests of variable interest entity subject to mandatory redemption	7.017		%	1.9	%	6.887		%	100.0	%	—		%
Discount notes	0.051		%	(34.6	)%	0.078		%	(1.3	)%	0.079		%
Blended	5.146		%	(2.4	)%	5.273		%	(5.7	)%	5.589		%

Notes

(1) Interest expense includes interest on long-term debt obligations, including amortization of debt discounts, issuance, and reacquisition costs, net.

(2) The average interest rates on long-term debt obligations reflected in the table above are calculated using an average of long-term debt balances at the end of each month in the periods depicted and interest expense for those periods.

2014 Compared to 2013

Net interest expense decreased $57 million for the year ended September 30, 2014. This was primarily attributable to a decrease in long-term interest expense of $58 million, related to a decrease in both the average balance and the average interest rate of TVA’s outstanding debt. See Note 13.

2013 Compared to 2012

Net interest expense decreased $47 million for the year ended September 30, 2013. This was primarily attributable to a decrease in interest expense of $78 million as a result of a decrease in the average interest rate of TVA's outstanding debt. This was partially offset by a $31 million increase primarily due to the amortization of debt reacquisition cost as a result of prior year refinancings and due to the financing of the John Sevier Combined Cycle Facility. See Note 9.

Liquidity and Capital Resources

Sources of Liquidity

To meet cash needs and contingencies, TVA depends on various sources of liquidity.  TVA’s primary sources of liquidity are cash from operations and proceeds from the issuance of short-term and long-term debt.  Current liabilities may exceed current assets from time to time in part because TVA uses short-term debt to fund short-term cash needs as well as to pay scheduled maturities and other redemptions of long-term debt. The daily balance of cash and cash equivalents maintained is based on near-term expectations for cash expenditures and funding needs.

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 U.S. Treasury, three long-term revolving credit facilities totaling $2.5 billion,

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and proceeds from any other financing arrangements such as lease financings, call monetization transactions, sales of assets, and sales of receivables and loans.  Management expects these sources, certain of which are described below, to provide adequate liquidity to TVA for the foreseeable future. 

The TVA Act authorizes TVA to issue Bonds in an amount not to exceed $30.0 billion outstanding at any time.  At September 30, 2014, TVA had $23.6 billion of Bonds outstanding (not including noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million). Due to this limit on the amount of outstanding Bonds, TVA may not be able to use Bonds to finance all of the capital investments planned over the next decade. However, TVA believes that other forms of financing not subject to the limit on Bonds, including lease financings (see Lease Financings below and Note 9), can provide supplementary funding. Also, the impact of energy efficiency and demand response initiatives may reduce generation requirements and thereby reduce capital needs.  TVA anticipates that capital spending needs can be met with a combination of Bonds, lease arrangements, energy prepayments, additional power revenues through rate increases, cost reductions, or other ways.

Issuance of Debt.  Bonds are not obligations of the United States, and the United States does not guarantee the payments of principal or interest on Bonds.  Bonds consist of power bonds and discount notes. Power bonds have maturities of between one and 50 years. 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.  

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 testand 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;

• Payments to states and counties in lieu of taxes;

• Debt service on outstanding Bonds;

• 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 in advance of 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 17 — Appropriation Investment.

The rate test for the one-year period ended September 30, 2014, was calculated after the end of 2014, 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, 2010, was calculated after the end of 2010, and TVA met the test’s requirements.  TVA must next meet the bondholder protection test for the five-year period ending September 30, 2015.

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.  

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

Short-Term Borrowing Table
	At September 30 2014			For the year ended September 30 2014			At September 30 2013			For the year ended September 30 2013			At September 30 2012			For the year ended September 30 2012
Amount Outstanding (at End of Period) or Average Amount  Outstanding (During Period)
Discount notes	$	596		$	1,737		$	2,432		$	1,887		$	1,507		$	1,148
Weighted Average Interest Rate
Discount notes	0.002		%	0.051		%	0.042		%	0.078		%	0.085		%	0.079		%
Maximum Month-End Amount Outstanding (During Period)
Discount notes	N/A			$	2,442		N/A			$	3,261		N/A			$	2,550

TVA held a lower balance of short-term debt at September 30, 2014, than at September 30, 2013, due to debt portfolio management decisions.  The average balance of short-term debt was lower in 2014 than 2013 due to lower overall financing needs in 2014.  TVA held a higher balance of short-term debt at September 30, 2013, than at September 30, 2012, due to the timing of cash flows and debt portfolio management decisions. The average balance of short-term debt was higher in 2013 than 2012 due to heavy refinancing activity throughout the fiscal year and the decision to hold a higher percentage of the debt portfolio in short-term debt to take advantage of historically low short-term rates.  The variance in the average interest rate on discount notes is primarily due to changes in market conditions.

TVA uses a significant portion of its power bond proceeds to refinance previously-issued power bonds as they mature or are redeemed. From time to time, TVA also uses power bond proceeds for other power program purposes, including financing construction projects.

During 2014 and 2013, TVA issued $1.0 billion and $2.2 billion of power bonds, respectively, and redeemed $365 million and $2.4 billion of power bonds, respectively.  Power bonds outstanding, excluding unamortized discounts and premiums and net exchange losses from foreign currency transactions, at September 30, 2014 were $23.6 billion (including current maturities) and at September 30, 2013 were $24.8 billion (including current maturities). For additional information about TVA debt issuance activity and debt instruments issued and outstanding at September 30, 2014, and 2013, including rates, maturities, outstanding principal amounts, and redemption features, see Note 13 — DebtSecurities Activity and Debt Outstanding.

TVA Bonds are traded in the public bond markets. TVA's Bonds are listed on the New York Stock Exchange ("NYSE") except for TVA's discount notes, the 2009 Series A and 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 NYSE-listed bonds are assigned various symbols by the exchange, which are noted on the NYSE's web site. 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 United States, TVA, as a corporate agency and instrumentality of the United States government, may be impacted if the sovereign credit ratings of the United States are downgraded. According to statements made by nationally recognized credit rating agencies, the credit ratings of the United States government remain under negative pressure despite recent legislative developments, and additional fiscal measures may be needed to improve the outlook on the government's bond ratings. Additionally, TVA may be impacted by how the U.S. government addresses the situation of approaching its debt limit. In June 2013, one credit rating agency changed the outlook for the ratings of the United States from negative to stable, citing receding fiscal risks, and subsequently changed the outlook on TVA from negative to stable. In October 2013, one credit rating agency placed the ratings on the United States sovereign debt on rating watch negative, and subsequently placed TVA's rating on rating watch negative. Rating watch is typically event driven, while the negative status indicates a heightened probability of a downgrade. The outlook on TVA's ratings has subsequently been returned to stable, and Is currently stable with all three agencies.

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 2015 and has a maturity date of September 30, 2015. 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 plans to use the credit facility as 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 United States with maturities from date of issue of one year or less. There were no outstanding borrowings under the facility at

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September 30, 2014. The availability of this credit facility may be impacted by how the U.S. government addresses the situation of approaching its debt limit.

The following table provides additional information regarding TVA's funding available in the form of three long-term revolving credit facilities. The credit facilities accommodate the issuance of letters of credit. 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. See Note 13 — Credit Facility Agreements and Note 15 — Other Derivative Instruments — Collateral.

Summary of Long-Term Credit Facilities At September 30, 2014 (in billions)
Maturity Date	Facility Limit		Letters of Credit Outstanding		Cash Borrowings		Availability
June 2017	$	1.0	$	0.3	$	—	$	0.7
December 2017	1.0		0.2		—		0.8
April 2018	0.5		0.5		—		—
	$	2.5	$	1.0	$	—	$	1.5

Lease Financings. TVA has entered into certain leasing transactions with special purpose entities to obtain third-party financing for its facilities. These special purpose entities are sometimes identified as variable interest entities ("VIEs") of which TVA is determined to be the primary beneficiary. TVA is required to account for these VIEs on a consolidated basis. TVA may seek to enter into similar arrangements in the future, but has no immediate plans to do so. See Note 9.

Summary Cash Flows

A major source of TVA's liquidity is operating cash flows resulting from the generationand sales of electricity. A summary of cash flow components for the years ended September 30 follows:

Summary Cash Flows For the years ended September 30
	2014			2013			2012
Cash provided by (used in):
Operating activities	$	2,980		$	2,597		$	2,574
Investing activities	(2,756		)	(2,385		)	(2,513		)
Financing activities	(1,326		)	522			300
Net change in cash and cash equivalents	$	(1,102	)	$	734		$	361

Operating Activities

2014 Compared to 2013

Net cash flows provided by operating activities increased by $383 million in 2014 compared to 2013. This increase was due primarily to the $198 million increase in net income and the $175 million recovery of insurance proceeds related to the Kingston ash spill. Net income increased primarily as a result of the October 1, 2013 base rate increase, increases in heating and cooling degree days, and TVA’s continual efforts to improve cost management, working capital, and operational performance. These increases in cash flows from operating activities were partially offset by $250 million in pension contributions and a $35 million increase in costs deferred as a result of actions of TVA's regulator, primarily related to the deferred nuclear generating unit at Bellefonte. See Note 8 — Deferred Nuclear Generating Units and Construction Costs.

2013 Compared to 2012

Net cash flows provided by operating activities increased by $23 million in 2013 compared to 2012. This increase was due to the increase in net income, cash savings from the increased use of hydroelectric generation as a result of increases in rainfall and runoff, the use of coal inventories which had been built up during the prior year, and the decrease in TVA’s required posting of cash collateral associated with commodity hedges.  These items were partially offset by higher costs accrued in 2012, which were subsequently paid in 2013, compared to the significantly lower costs accrued at September 30, 2013, as a result of TVA’s efforts to improve cost management, working capital, and operational performance.

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Investing Activities

The majority of TVA's investing cash flows are due to investments in property, plant, and equipment for new generating assets and work on existing facilities, environmental projects, and transmission upgrades necessary to maintain reliability.

2014 Compared to 2013

Net cash flows used in investing activities increased $371 million in 2014 compared to 2013. The increase primarily reflects the $333 million increase in construction expenditures and $39 million increase in nuclear fuel expenditures. The construction expenditures increase is primarily related to the ongoing work on Watts Bar Unit 2, capacity expansion related to the natural gas-fired generation facilities at Paradise Fossil Plant ("Paradise") and Allen Fossil Plant ("Allen"), and environmental and clean air projects. The increase in nuclear fuel expenditures was due to TVA's purchasing nuclear fuel in advance of the five outages scheduled for 2015.

2013 Compared to 2012

Net cash flows used in investing activities decreased $128 million in 2013 compared to 2012. This change was primarily due to the timing, prioritization, and cancellation of certain capital projects.

Financing Activities

2014 Compared to 2013

Net cash flows used in financing activities was $1.3 billion in 2014 compared to $522 million of net cash flows provided by financing activities in 2013. The increase in cash flows used in financing activities was primarily due to net redemptions of debt of $1.2 billion during 2014, as compared to net issuances of debt of $1.0 billion during 2013. This $2.2 billion change in net debt issuances and redemptions was primarily due to less power bonds maturing in 2014 compared to 2013 and strategic decision to use cash on hand during 2014 to meet some of its near-term capital funding needs.

2013 Compared to 2012

Net cash flows provided by financing activities increased $222 million in 2013 compared to 2012 due to an increase in the net issuances of debt as a result of TVA’s election to maintain higher cash balances due to the timing of cash flows and debt portfolio management decisions. See Liquidity and Capital Resources — Sources of Liquidity — Issuance of Debt. The increase of Payments on leases and leasebacks is due to the reacquisition of the Southaven CCF, the financing of which resulted in proceeds from a $360 million secured notes issuance and the issuance of $40 million of membership interests. See Note 9— Southaven.

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Cash Requirements and Contractual Obligations

The future planned construction expenditures for property, plant, and equipment additions, including clean air projects and new generation, are estimated to be as follows:

Construction Expenditures(1) As of September 30
	Actual				Estimated Construction Expenditures
	2014				2015		2016		2017
Watts Bar Unit 2	$	724			$	604	$	63	$	—
Other capacity expansion expenditures	170				1,005		687		815
Environmental expenditures	333				296		197		108
Coal combustion residual	94				77		49		51
Transmission expenditures	301				345		414		394
Other capital expenditures(2)	700				790		794		804
Total construction expenditures	$	2,322	(3	)	$	3,117	$	2,204	$	2,172

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.

(3)  The numbers above exclude AFUDC, capitalized during the year, related to construction expenditures, of $175 million and include construction in progress expenditures accrued in Accounts payable and accrued liabilities of $113 million.

TVA continually reviews its construction 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.

In the near term, TVA’s cash flows may be negatively impacted by investments in new generation, such as Watts Bar Unit 2, that are not expected to provide a cash return until put into service.

TVA has certain obligations and commitments to make future payments under contracts, including contracts executed in connection with certain of the planned construction expenses.  The following table sets forth TVA’s estimates of future payments at September 30, 2014.  See Note 9, Note 10, Note 11, Note 13, Note 17, and Note 21 for a further description of these obligations and commitments.

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Commitments and Contingencies Payments due in the year ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Debt(1)	$	1,628	$	32	$	1,555	$	1,682	$	1,032	$	17,692	$	23,621
Interest payments relating to debt	1,220		1,176		1,162		1,073		998		17,129		22,758
Debt of VIEs	32		33		35		36		38		1,137		1,311
Interest payments relating to debt of VIEs	60		58		58		56		54		693		979
Lease obligations
Capital	13		13		13		13		12		167		231
Non-cancelable operating	38		36		34		27		25		63		223
Purchase obligations
Power	220		222		232		235		239		3,364		4,512
Fuel	1,335		862		477		552		492		1,579		5,297
Other	304		215		202		199		192		1,640		2,752
Environmental Agreements	54		66		41		2		—		—		163
Membership interests of variable interest entity subject to mandatory redemption	2		2		2		2		2		29		39
Interest payments related to membership interests of variable interest entity subject to mandatory redemption	3		3		2		2		2		15		27
Flood response commitment to NRC	11		7		—		—		—		—		18
Litigation settlements	9		—		—		—		—		—		9
Unfunded loan commitments	13		—		—		—		—		—		13
Environmental cleanup costs-Kingston ash spill	21		—		—		—		—		—		21
Payments on other financings	104		104		104		104		96		305		817
Payments to U.S. Treasury - Return on Power Program Appropriation Investment	5		8		8		8		8		85		122
Retirement Plan(2)	215		—		—		—		—		—		215
Total	$	5,287	$	2,837	$	3,925	$	3,991	$	3,190	$	43,898	$	63,128

Note

(1) Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million.

(2) The Tennessee Valley Authority Retirement System calculates TVA's minimum required annual contribution to the pension plan prior to the beginning of each fiscal year based on pension plan rules. The amount listed for 2015 is the minimum required contribution, and the calculation has not yet been completed for any years beyond 2015. See Note 20.

In addition to the obligations above, TVA has energy prepayment obligations in the form of revenue discounts. See Note 1 — Energy Prepayment Obligations and Discounts on Sales.

Energy Prepayment Obligations Obligations due in the year ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Energy Prepayment Obligations	$	100	$	100	$	100	$	100	$	10	$	—	$	410

EnergyRight^® Solutions Program. TVA purchases certain loans receivable from its LPCs in association with the EnergyRight^® Solutions program. 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, 2014, the total carrying amount of the loans receivable, net of discount, was approximately $156 million. Such amounts are not reflected in the Commitments and Contingencies table above. The total carrying amount of the financing obligation was approximately $190 million at September 30, 2014. See Note 7 and Note 11 for additional information.

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Off-Balance Sheet Arrangements

At September 30, 2014, TVA had no off-balance sheet arrangements.

Key Initiatives and Challenges

Generation Resources

Nuclear Response Capability. Since the events that occurred in 2011 at the Fukushima Daiichi Nuclear Power Plant, the NRC has issued and adopted additional detailed guidance on the expected response capability to be developed by each nuclear plant site. TVA submitted integrated strategies to the NRC on February 28, 2013. TVA has developed plans and schedules for the development and implementation of strategies and physical plant modifications to address the actions outlined in this guidance for all of its plants, including Watts Bar Unit 2. The initial studies, including the required plant walkdowns, have been completed. Flooding re-evaluations to determine any further plant modifications are scheduled for completion in mid-2015. Cost estimates for any required modifications cannot be developed until after the analyses are complete, but costs for modifications could be substantial.

Extreme Flooding Preparedness. Updates to the TVA analytical hydrology model have indicated that under “probable maximum flood” conditions, some of TVA’s dams might not be capable of regulating the higher flood waters. A “probable maximum flood” is an extremely unlikely event, and TVA has developed a program for current and future dam modifications with the aim of ensuring that in the case of such an event, flood waters would pass safely and would not impact sensitive or vital equipment at the nuclear plant sites. TVA implemented temporary dam modifications in 2010 to raise the height of four dams, and permanent modifications are underway. TVA has made a commitment to the NRC to complete permanent raising of these four dams by October 31, 2015, except for a portion of the modifications to one dam that will not be completed until February 1, 2017. Additionally, TVA is upgrading the structural stability of two dams to withstand higher flood waters and has plans to upgrade four dams to support long-term improvement to flood mitigation margin. As of September 30, 2014, TVA had spent $83 million on these modifications, and expects to spend an additional $75 million to complete the modifications.

Seismic Assessments. On May 9, 2014, the NRC notified licensees of nuclear power reactors in the central and eastern United States of the results of seismic hazard screening and prioritization evaluations performed by the NRC staff. Because the seismic hazards for Bellefonte Nuclear Plant ("Bellefonte"), Browns Ferry, Sequoyah, and Watts Bar exceed their seismic design basis, TVA must conduct seismic risk evaluations for these plants. TVA must complete the evaluation for Watts Bar by June 30, 2017, and the evaluations for Browns Ferry, Sequoyah, and Bellefonte by December 31, 2019. These evaluations could result in TVA having to make modifications to one or more of its nuclear plants. Cost estimates for any required modifications cannot be developed until after the evaluations are complete, but costs for modifications could be substantial.

Watts Bar Unit 2. Construction of Watts Bar Unit 2 is continuing in accordance with the schedule and budget

expectations approved by the TVA Board in April 2012. The total estimated cost of completion is in the range of $4.0 billion to $4.5 billion. The project team has shifted its focus from large-scale construction to completion and testing of individual plant systems including integrated systems testing. In September 2014, primary cold hydrostatic testing to ensure that key reactor equipment and systems did not leak or fail under pressure was successfully completed. The testing was an important milestone for the site and for TVA, because it marks a significant step toward integrating the unit into the TVA nuclear fleet. Final documentation of the testing is still in progress.

The regulatory reviews associated with the issuance of an NRC operating license are continuing. The NRC issued an extension to the Watts Bar Unit 2 construction permit on November 21, 2013. The revised permit expires on September 30, 2016. The NRC reviews of TVA’s actions associated with post-Fukushima requirements are underway and are not currently anticipated to result in any concerns that would affect the timely issuance of an operating license. Resolution of the waste confidence issue helped mitigate a significant risk related to the completion date of Watts Bar Unit 2. See Waste Confidence Rule below.

Challenges to the project include completing complex work and required documentation; reverification of previously completed systems; addressing emergent work identified during testing; current and emergent licensing issues; and successfully transitioning the site into dual-unit operation. Although the fuel load for Unit 2 has been delayed and is now expected to begin in May 2015, TVA still plans to bring Watts Bar Unit 2 into commercial operation by December 2015.

Bellefonte Unit 1. Although work on the Bellefonte Unit 1 site was slowed in 2014, TVA believes that the resulting budgeting and staffing levels should be sufficient to preserve Bellefonte for potential future development. TVA plans to utilize its integrated resource planning process to help determine how Bellefonte best supports TVA's overall efforts to continue to meet customer demand with low-cost, reliable power.

Nuclear Generation. In October 2010, while Browns Ferry Unit 1 was shut down for a scheduled refueling outage, TVA discovered a low pressure coolant injection valve had experienced an unanticipated failure. The NRC concluded that the valve

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failure, and TVA's inability to identify the failure, was an issue of “high safety significance” (which is termed a “red” finding under the NRC's Reactor Oversight Process) and designated Browns Ferry in the “multiple/repetitive degraded cornerstone” category in its performance assessment process. As a result of this designation, Browns Ferry was subject to substantially higher NRC oversight. A series of intensive inspections and assessments began in the fall of 2011. On January 30, 2014, the NRC announced the results of its inspections and closed the red finding. The NRC has since announced that all of the Browns Ferry units have returned to the normal oversight category.

Spent Fuel. Under the Nuclear Waste Policy Act of 1982, generators of nuclear energy were historically required to pay a fee of one-tenth of a cent per kilowatt-hour into the Department of Energy ("DOE") nuclear waste fund. TVA’s annual payments into this fund ranged from $50 million to $55 million in recent years. In November 2013, the U.S. Court of Appeals for the District of Columbia Circuit ordered the DOE to stop collecting nuclear waste fees until either (1) the DOE complies with the Nuclear Waste Policy Act of 1982 or (2) the U.S. Congress enacts an alternative waste management plan. In accordance with the court’s order, the DOE submitted a proposal to the U.S. Congress in January 2014 to change the nuclear waste fee to zero, and as of May 16, 2014, the DOE ceased collecting this fee. TVA avoided approximately $20 million in 2014, and if the fee remains at zero, TVA estimates that it will avoid approximately $52 million in 2015. Any such savings will be passed on to TVA’s customers through the fuel cost adjustment.

Waste Confidence Rule. On August 26, 2014, the NRC approved a final rule on the environmental effects of continued storage of spent nuclear fuel and terminated a two-year suspension of final licensing actions for nuclear power plants and renewals. The rule, renamed the “Continued Storage of Spent Nuclear Fuel Rule,” adopts findings from a supporting generic environmental impact statement and concludes that spent nuclear fuel can be safely managed in dry casks indefinitely. Issuance of this rule helped mitigate a significant risk to the timely completion of Watts Bar Unit 2 and may alleviate some issues in the relicensing processes related to Sequoyah while helping ensure compliance with the requirement of the National Environmental Policy Act to disclose the environmental impacts of used fuel storage.

See Note 21— Legal Proceedings — Administrative Proceedings Regarding Watts Bar Unit 2, — Administrative Proceeding Regarding Renewal of Operating License for Sequoyah Nuclear Plant, and — Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage for additional information.

Coal-Fired Units. The decision to idle or retire coal-fired units from TVA's generation fleet is being influenced by several factors including the two environmental agreements reached in April 2011 (the "Environmental Agreements"), the cost of adding emission control equipment and other environmental improvements (see Note 21 — Legal Proceedings — Environmental Agreements), fuel prices, condition of plants, and demand for energy.  Under the Environmental Agreements, TVA committed, among other things, to retire, on a phased schedule, 18 coal-fired units.  As of September 30, 2014, per the requirements of the Environmental Agreements, TVA had retired 11 coal-fired units with a summer net capability of 1,494 megawatts ("MW"). During 2014, TVA notified the respective states of the retirement of John Sevier Fossil Plant Units 3 and 4 and Shawnee Fossil Plant ("Shawnee") Unit 10 from the Environmental Protection Agency ("EPA") emission allowance and reporting system, rendering these units inoperable.

TVA continues to assess its power generating facilities, including its aging coal-fired fleet. As of September 30, 2014, TVA had removed from service, mothballed, and/or idled an additional seven coal-fired units beyond those covered by the Environmental Agreements with a summer net capability of 1,250 MW. 

Under terms of the Environmental Agreements, TVA must decide whether to install additional air pollution controls on Units 1 and 4 at Shawnee, convert those units to burn biomass, or retire them by December 31, 2017.  See Note 21 — Legal Proceedings — Environmental Agreements.  The decision on Units 1 and 4 must be communicated to the EPA and the other participants by December 31, 2014. TVA is preparing an Environmental Assessment to help decide the future of Units 1 and 4, which have a summer net capability of 268 MW. The options to install scrubbers and selective catalytic reduction controls or permanently retire the units will be examined in more detail in the Environmental Assessment. There are seven additional operating coal-fired units at Shawnee that are not covered by the Environmental Agreements. See Part I, Business — Power Supply —Coal-Fired.

During 2014, the TVA Board took several actions related to the retirement of certain coal-fired units. Upon the completion of natural gas-fired generation facilities at the Paradise site, coal-fired Units 1 and 2 at Paradise with a summer net capability of 1,230 MW will be retired, and upon the completion of a natural gas-fired generation facility at the Allen site, coal-fired Units 1-3 at Allen with a summer net capability of 741 MW will be retired. The TVA Board also approved the retirement of Colbert Units 1-5 with a summer net capability of 1,184 MW no later than June 30, 2016, as well as the retirement of Widows Creek Unit 8 with a summer net capability of 465 MW in the future. See Natural Gas-Fired Units.

Natural Gas-Fired Units. At its November 14, 2013 meeting, the TVA Board approved the completion of a natural gas-fired generation facility with an expected generation capacity of approximately 1,000 MW at TVA’s Paradise site at a cost not to exceed $1.1 billion. A lawsuit has been filed challenging TVA's Paradise decision. See Note 21 — Legal Proceedings — National Environmental Policy Act Challenge at Paradise Fossil Plant. An injunction or court order that delays TVA's plans at Paradise could increase the project's cost. On August 21, 2014, the TVA Board approved the construction of a natural gas-fired generation facility also with an expected generation capacity of approximately 1,000 MW at the Allen site at a cost not to exceed

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$975 million. Upon completion of each facility, existing coal-fired units at each site will be retired with the exception of Paradise Unit 3, which would continue to be operated on the Paradise site.

Status of Other Generation Units. Units 1-4 at Raccoon Mountain Pumped-Storage Plant ("Raccoon Mountain"), with a total net summer capability of 1,616 MW, were taken out of service for maintenance activities in 2012 after an inspection of the turbines in each unit identified cracking in the rotor poles and the rotor rims. All four units have subsequently completed maintenance overhauls to correct these cracking problems.  However, an unrelated issue was identified in certain oil-filled power cables that convey power out of the facility, resulting in TVA limiting service to three units until resolved. As of September 30, 2014, three of the four Raccoon Mountain units were in service. The return to service date for the fourth unit is estimated to be in the third quarter of 2015.

Small Modular Reactors. TVA is preparing an early site permit application to the NRC to license small modular reactors ("SMRs") at TVA’s Clinch River Site in Oak Ridge, Tennessee. TVA continues with to interact with Babcock & Wilcox ("B&W") through the contract entered into in February 2013, to support TVA's licensing activities and is participating in a cost-share industry partnership program between the DOE and B&W.

TVA’s site characterization work that will support an early site permit application for planned submittal to the NRC in the fall of 2015 is progressing. Submittal of a subsequent construction and operating license application is subject to a future TVA decision to proceed and will follow submittal of one or more Design Certification Applications to the NRC by SMR vendors. The construction and operating license application is not expected to be submitted before 2017.

Distributed Generation. As technologies for producing energy on solar, small gas, and other types of sites are evolving, they are becoming cost competitive and more reliable, and consumers are having a greater desire to utilize these technologies for their own needs. Previously, the limited impact of electricity from the small numbers of these distributed generation sites was easily absorbed within the capacity of a system the size of TVA’s. However, as the amount of distributed generation grows on the system, the ability of the system to cope with these generation sources becomes more challenging while at the same time reducing the need for TVA’s generation resources. TVA, in conjunction with interested LPCs and other stakeholders, is investigating the value and challenges these resources provide to the grid in order better understand their impact and determine how they can best be integrated into the TVA system. As distributed generation continues to expand across the Tennessee Valley, TVA and LPC’s will continue to focus significant attention on the safety of these resources as they are interconnected to the grid. Financial implications cannot be determined at this time.

Cost Reduction Initiatives

TVA is undertaking cost reduction initiatives with the goal of reducing operating and maintenance costs by $500 million by 2015 as compared to its 2013 budget. This objective is an effort to keep rates low, keep reliability high, and continue to fulfill its broader mission of environmental stewardship and economic development. To position itself to achieve this goal, TVA, in conjunction with other actions, completed a high-level realignment of its strategic business units during 2013 and 2014. Business unit leaders will work to identify ways to further streamline their organizations to achieve 2015 operating and maintenance cost-reduction targets by eliminating unnecessary work; increasing productivity; minimizing overlaps, redundancies, and handoffs; and ensuring that accountability for compliance rests with its line organizations. At the end of 2014, TVA had exceeded its $300 million target on operating and maintenance cost savings for the year and positioned itself to achieve its cost reduction goal of $500 million by the end of 2015.

Given that approximately 80 percent of TVA's operating and maintenance costs are related to labor, staffing level reductions necessarily resulted from this process. Approximately 2,000 position reductions were achieved through attrition, elimination of vacant positions, and employees leaving TVA either voluntarily or involuntarily. Certain employees were eligible for severance payments as a result of these cost reduction initiatives. As of September 30, 2014, TVA had $45 million accrued related to estimated future severance payments. See Note 3.

Regulatory Compliance

Coal Combustion Residual Facilities. As a result of the December 2008 ash spill at Kingston, TVA retained an independent third-party engineering firm to perform a multi-phased evaluation of the overall stability and safety of all existing embankments associated with TVA’s wet coal combustion residual ("CCR") facilities. The study showed that none of TVA’s other coal-fired plants presented risks similar to the conditions that existed at Kingston at the time of the ash spill, and that the ongoing remediation work being done at the plants should bring all of them within industry standards in terms of stability upon completion. Implementation of recommended actions is ongoing, including risk mitigation steps such as performance monitoring, designing and completing repairs, developing planning documents, obtaining permits, and generally implementing the lessons learned from the Kingston ash spill at TVA’s other CCR facilities.

TVA is planning to convert its wet ash and gypsum facilities to dry storage collection facilities. The expected cost of the CCR work is between $1.5 billion and $2.0 billion, and the work is expected to be completed by December 2022. As of September 30, 2014, $618 million of costs had been incurred since the start of the work.

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TVA is studying the adequacy of CCR storage capacity at its coal-fired plants that currently have dry storage collection facilities. If it is determined that the remaining capacity is not adequate, additional storage facilities will need to be permitted and built, or off-site disposal will need to be arranged.

Transmission Issues. TVA anticipates expenditures to increase as a result of both new and evolving compliance regulations.  On October 17, 2013, the North American Electric Reliability Corporation ("NERC") approved revisions to the Transmission Planning ("TPL") Reliability Standards.  TVA began preliminary work on these standards in 2006.  TVA anticipates spending $77 million on existing transmission facilities between 2015 and 2017 to ensure compliance with the 2013 version of the TPL standards. TVA will continue to evaluate the impact of these standards on existing facilities, including the associated costs, beyond 2017. Costs beyond 2017 are expected to be significant.

On November 21, 2013, the Federal Energy Regulatory Commission ("FERC") approved NERC Critical Infrastructure Protection ("CIP") Version 5 Reliability Standards ("Version 5"). Version 5 does not add or remove any substantial physical security requirements; however, it does significantly increase the number of sites within the scope of these standards.  TVA anticipates spending $40 million on existing transmission facilities from 2015 through 2018 to ensure compliance with Version 5 standards. TVA will continue to evaluate the impact of these standards on existing facilities.

On March 7, 2014, FERC issued an order for the development of new physical security standards that will mandate the identification and protection of the nation's most critical transmission substations and their associated primary control centers. This new standard, NERC CIP-014-1 — Physical Security, was submitted to FERC for approval on May 23, 2014. On July 17, 2014, in a notice of proposed rulemaking, FERC requested revisions to the proposed standard that will require NERC to develop modifications that will delay the implementation beyond the originally projected enforcement date of April 2015. TVA continues to evaluate measures that may be required for compliance, but costs cannot be estimated at this time.

In May 2013, FERC issued Order No. 779 directing NERC to develop reliability standards addressing the potential impact of geomagnetic disturbances ("GMDs") in two stages.  The Stage 1 standard, Emergency Operations Planning ("EOP")-010-1, Geomagnetic Disturbance Operations, which requires GMD operating procedures, was approved by FERC on June 19, 2014.  The Stage 2 standard, TPL-007-1, Geomagnetic Disturbance Mitigation, which must be filed by January 2015, will require entities to conduct assessments of the impacts of benchmark GMD events on their systems and to develop plans to mitigate the risk of instability, uncontrolled separation, and cascading. Costs for compliance with EOP-010-1 and TPL-007-1 are not known at this time.

Dam Safety 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 to modern industry criteria using the new probable maximum flood and site- specific seismic load cases.    

One aspect of the guidelines is that dam structures will be periodically reassessed to assure that TVA's dams meet current design criteria. These reassessments include material sampling of the dam and foundational structures and detailed engineering analysis. TVA is currently performing reassessments on its 49 dam projects. Twenty-eight reassessments have been completed, and the remaining 21 reassessments are scheduled to be completed by the fourth quarter of 2017. Ten assessments are scheduled to begin in 2015. To date, TVA has spent $27 million on the dam safety assurance program, and TVA expects to spend an additional $25 million in 2015.

It is expected that projects will be identified after these reassessments, and the work will be appropriately prioritized and completed within TVA’s capital improvement process. See Extreme Flooding Preparedness.

As part of the dam safety reassessments, initial data from a seismic stability assessment of Pickwick Landing Dam in western Tennessee showed the factor of safety during a large earthquake for the south embankment dam (earthen section south of the concrete section) was unacceptable based on current TVA and industry standards. Conditions at the dam have not changed; however, in the remote chance that a large seismic event occurs along the New Madrid Fault in western Tennessee, it may cause damage to the earthen embankment dam. In order to ensure public safety and to evaluate Pickwick Landing Dam further, TVA has elected to draw down the Pickwick Landing Reservoir to winter pool level at an accelerated rate and continue to analyze the data and develop a path forward to address this issue. A project has been developed to further analyze the embankment, perform environmental reviews, and develop design remediation plans starting in 2015. The concrete portion of the dam will also be evaluated in 2015. Cost estimates for any required remediation cannot be developed until after the analyses are complete.

Ratemaking

TVA's rates are below the national average and TVA has established a goal to keep rates low as benchmarked against the nation's 100 largest utilities. TVA understands the importance of competitive rates as a key to its economic development

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mission of providing low-cost power to the people of the Tennessee Valley. In support of this goal, TVA continues to review and modify its rate structure to meet the needs of its customers.

For LPCs, the default wholesale rate structure is seasonal time-of-use ("TOU"). However, these customers have two additional wholesale options from which to elect: enhanced TOU and enhanced seasonal demand and energy ("SDE"). As of October 1, 2014, 148 were served under the enhanced TOU structure, two remained served under the default seasonal TOU structure, and five were served under the enhanced SDE structure.

On August 21, 2014, the TVA Board approved a non-fuel base rate increase of 2.61 percent on wholesale rates. It is anticipated this will increase base revenues by approximately $199 million for 2015.

TVA is working closely with its customers on the development of a strategic pricing plan. This plan is to be a collaborative effort to define the long-term direction for pricing which will allow TVA to best serve the Tennessee Valley by maintaining competitive and affordable rates. The process will look at rate structure, pricing products and programs, and TVA’s competitive position across rate classes. A rate change letter is scheduled to be issued to the LPCs in January 2015 notifying TVA’s customers of its intent to modify its rate structure in October 2015.

Pension Fund

On April 11, 2014, the Tennessee Valley Authority Retirement System ("TVARS") Board approved amendments to the qualified defined benefit plan effective June 30, 2014. These amendments close the defined benefit plan to new employees and certain rehires. These employees will be eligible for a retirement benefit as participants in the defined contribution plan only. The benefit structures of the qualified defined benefit plan for current employees and retirees — Original Benefit Structure and Cash Balance Benefit Structure — have not been changed. The provisions of the defined contribution plan for these employees will also remain unchanged. See Note 20.

As of September 30, 2014, TVA's qualified pension plan had assets of $7.5 billion compared with liabilities of $12.2 billion. The potential for the plan's funded status to quickly improve is limited because of the significant amount of benefits paid each year to plan beneficiaries. The plan currently has approximately 35,200 participants, of which approximately 23,400 are retirees and beneficiaries currently receiving benefits. Benefits of approximately $650 million were paid to participants in 2014.

Pending Environmental Regulation and Legislation

TVA anticipates that there will continue to be additional, more stringent air, water, and waste regulatory requirements governing the production and transmission of electricity. TVA also expects future regulations will require the reduction of carbon dioxide emission from current levels. The cost of compliance for these measures is unknown but could require significant expenditures. TVA continues to monitor the changes and pursue actions that limit the impacts of these requirements on its operations. See Item 1, Business — Power Supply and — Environmental Matters.

Inflation

Given the current low levels of capacity utilization and high unemployment, inflationary pressures should remain low. However, a strong, sustained recovery with increasing labor, construction, and commodity costs, as well as high interest rates, could result in higher costs for TVA and pressure to increase power rates.

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, transport, and deliver power to its customers. TVA's Police and Emergency Management are active participants with numerous professional and peer physical security organizations in both the electric industry and law enforcement communities.

Recent physical attacks at other utilities on transmission facilities across the country have heightened awareness. TVA is working with the Department of Homeland Security ("DHS"), FERC, Edison Electric Institute, Electric Power Research Institute, and other utilities to implement industry approved recommendations and standards. See Key Initiatives and Challenges — Regulatory Compliance — Transmission Issues.

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 nuclear security forces to guard against such threats.

Cyber Security. Cyber security is a serious and ongoing challenge for the energy sector. TVA faces potential cyber attacks against its generation facilities, the transmission infrastructure used to transmit power, and its information technology systems and network infrastructure, which could negatively impact the ability of TVA to generate, transport, and deliver power, or

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otherwise operate its facilities in the most efficient manner. If TVA's technology systems were to fail or be breached and were not recovered in a timely manner, TVA might be unable to fulfill critical business functions, and sensitive and other data could be compromised. The theft, damage, or improper disclosure of sensitive electronic data may also subject TVA to penalties and claims from third parties.

TVA operates in a highly regulated environment. TVA's cyber security program aligns or complies with the Federal Information System Management Act, the North American Electric Reliability Corporation Critical Infrastructure Protection requirements, and the NRC requirements for cyber security, as well as industry best practices. As part of the U.S. government, TVA coordinates with and works closely with the DHS and the United States Computer Emergency Readiness Team ("US-CERT"). US-CERT functions as a liaison between the DHS and the public and private sectors to coordinate responses to security threats from the internet. TVA is also participating in studies funded through the DOE to identify, design, and test new solutions for protecting critical infrastructure from cyber attacks.

Although TVA, as others, continued to experience increased cyber activity in 2014, none of the attacks impacted TVA's ability to operate as planned or compromised data which could involve TVA in legal proceedings. See Item 1A, Risk Factors — TVA's facilities and information infrastructure may not operate as planned due to physical and cyber threats to TVA's security.

Critical Accounting Policies and Estimates

TVA's consolidated financial statements are prepared in accordance with 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 in this Annual Report.

TVA believes that its most critical accounting policies and estimates relate to the following:

• Regulatory Accounting

• Asset Retirement Obligations

• 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.

Description	Judgments and Uncertainties	Effect if Actual Results Differ From 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 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. 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, 2014, TVA had $9.5 billion of Regulatory assets and $184 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.	TVA has not made any material changes in the accounting methodology used to record regulatory assets and liabilities during the past three fiscal years. 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 earnings.

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Description	Judgments and Uncertainties	Effect if Actual Results Differ From Assumptions
Asset Retirement Obligations
TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets. These obligations relate to fossil fuel-fired generating plants, nuclear generating plants, hydroelectric generating plants/dams, transmission structures, and other property-related assets. Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site reclamation. Revisions to the amount and timing of certain cash flow estimates of asset retirement obligations ("AROs") may be made based on engineering studies. For nuclear assets, site specific decommissioning cost estimate studies are obtained at least every five years. For non-nuclear obligations, revisions are made whenever factors indicate that the timing or amounts of estimated cash flows have changed. Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset. See Note 12.

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Description	Judgments and Uncertainties	Effect if Actual Results Differ From Assumptions
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 value of the capitalized asset and allocated to expense over the useful life of the 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. Changes in assumptions and estimates included within the calculations of the fair value of AROs could result in significantly different results than those identified and recorded in the financial statements. TVA periodically reviews its estimated ARO costs. Any change to the ARO asset is recognized and prospectively recognized over the remaining life of the long-lived asset. At September 30, 2014, the present value of the estimated future nuclear decommissioning cost recognized in the financial statements was $2.1 billion and was included in AROs, and the unamortized regulatory asset related to ARO costs of $931 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 - 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 a multiple unit site, the estimated retirement date is based on the unit with the longest license period remaining.) Second, an assumption must be made on the timing of the decommissioning. Prior to June 30, 2014, TVA based its decommissioning cost estimates on cost elements prescribed by the NRC to dismantle and decommission the radioactive portion of each site with the assumption that decommissioning would occur within the first seven years after plant shut down, which approximates the DECON method of decommissioning. The DECON method requires that radioactive contamination is 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. On June 30, 2014, TVA recorded a change in estimate based on the implementation of site-specific decommissioning cost studies. Additionally, TVA determined it appropriate to reflect an increase in the probability that certain of its nuclear operating licenses will be extended and that there is a probability that it will be able to delay ultimate decommissioning activities under a SAFSTOR method of decommissioning. 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. As such, TVA ascribed probabilities to both the SAFSTOR and DECON methods of decommissioning in order to estimate its decommissioning obligation. Decommissioning cost studies will be updated for each of TVA’s nuclear units at least every five years. While the impact of these assumptions cannot be determined with precision, either assuming license extension or extending the timing of decommissioning can significantly decrease the present value of these obligations. Technology and Regulation - 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. Discount Rate - TVA uses rates between 1.85 percent and 5.52 percent to calculate the present value of the weighted estimated cash flows required to satisfy TVA's decommissioning obligation.	A 10 percent change in TVA's ARO for nuclear decommissioning cost at September 30, 2014, would have affected the liability by approximately $210 million.

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Description	Judgments and Uncertainties	Effect if Actual Results Differ From Assumptions
Non-Nuclear Decommissioning
The present value of the estimated future non-nuclear decommissioning cost was $1.1 billion at September 30, 2014.  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 following key assumptions can have a significant effect on estimates related to the non-nuclear decommissioning costs: Timing – In projecting non-nuclear decommissioning costs, the date of the asset’s retirement must be estimated. TVA uses a probability-weighted scenario approach based on management assumptions, type of asset, and other factors to estimate the expected retirement time period. 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. 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 studies generally assume current technology and regulations. With respect to the CCR facilities, TVA assumes that any future closures will require more costly materials and processes than what is legally required at September 30, 2014. 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 non-nuclear decommissioning obligation. At September 30, 2014, the discount rates used in the calculations range from 0.21 percent to 11.00 percent.	TVA has not made any material changes in the accounting methodology used to record the non-nuclear ARO liability during the past three fiscal years. 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 non-nuclear decommissioning costs at September 30, 2014, would have affected the liability by approximately $110 million.

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Description	Judgments and Uncertainties	Effect if Actual Results Differ From Assumptions
Pension and Other Post-Retirement Benefits
TVA sponsors a defined benefit pension plan that is qualified under Internal Revenue Service rules and covers substantially all of its full-time annual employees hired prior to July 1, 2014.  On July 1, 2014, the qualified defined benefit pension plan was closed to new employees. Tennessee Valley Authority Retirement System ("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 its 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 and asset class factors. 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 current asset allocation policy approved by the TVARS Board diversifies plan assets across multiple asset classes so as to minimize the risk of large losses. The asset allocation policy is designed to be dynamic in nature and responsive to changes in the funded status of TVARS. Changes in the expected return rates are based on annual studies performed by third party professional investment consultants. Based upon the results from the 2014 annual study, TVA adjusted the assumption from 7.25 percent that was used to measure the 2014, 2013 and 2012 net periodic pension benefit cost, to a 7.00 percent expected rate of return that will be used to measure the 2015 net periodic pension benefit cost.	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 are amortized into periodic expense 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 active employees. Expected Return on Plan Assets. 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.  Since the market-related value of assets recognizes investment gains and losses over a three-year period, the future value of assets will be impacted as previously deferred gains or losses are recognized.  As a result, losses that the pension plan assets experience may have an adverse impact on pension expense in future years depending on whether the actuarial losses at each measurement date exceed 10 percent of the greater of the projected pension benefit obligation or the market-related value of plan assets in accordance with current accounting methodologies. The actuarial gain related to the difference between expected and actual return on pension plan assets for 2014 and 2013 was $213 million and $358 million, respectively. Compared with the assumed return of 7.25 percent, the 2014 and 2013 actuarial gains are due to the actual rates of return on the fair value of assets of 9.29 percent and 11.69 percent, respectively. The differences between expected and actual returns that result in an actuarial gain or loss are recognized as a decrease or increase, respectively, in the related regulatory asset and the projected pension benefit obligation. A higher expected rate of return assumption decreases the net periodic pension benefit cost, whereas a lower expected rate of return assumption increases the net periodic pension benefit cost. A 0.25 percent decrease in the expected rate of return on plan assets would increase the 2014 net periodic pension cost by $15 million. Changes in the expected rate of return on pension plan assets do not affect TVA’s post-retirement benefit plans because TVA does not separately set aside assets to fund such benefits. TVA funds its post-retirement plan benefits on an as-paid basis. These changes in the expected rate of return on pension plan assets also do not impact the Supplemental Executive Retirement Plan ("SERP") as any assets set aside for that plan are not considered plan assets under accounting principles generally accepted in the United States of America ("GAAP").

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Description	Judgments and Uncertainties	Effect if Actual Results Differ From Assumptions
	Compensation Increases.  Assumptions related to compensation increases are based on the results obtained from an actual TVA experience study performed during the most recent five years for plan participants. TVA obtained an updated study in 2013 and determined that future compensation would increase at rates between 3.50 percent and 13.00 percent per year, depending upon the employee's age. Based upon the current active participants, the average assumed compensation increases used to determine benefit obligations for 2014 and 2013 were 5.70 percent and 5.72 percent, respectively. The average assumed compensation increases used to determine net periodic pension cost for 2014, 2013, and 2012 were 5.72 percent, 4.44 percent, and 4.43 percent, respectively. Discount Rate. In the case of selecting an 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 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. The discount rates used to determine the pension and other post-retirement benefit obligations were 4.45 percent and 4.50 percent, respectively, at September 30, 2014. At September 30, 2013, the discount rates used to determine the pension and other post-retirement benefit obligations were 5.00 percent and 5.05 percent, respectively. The discount rate assumptions used to determine the obligations at year-end are used to determine the net periodic benefit cost for the following year. TVA will use discount rates of 4.45 percent and 4.50 percent to estimate its 2015 pension and other post-retirement net periodic benefit costs, respectively. The discount rate is somewhat volatile because it is determined based upon the prevailing rate as of the measurement date. Mortality. Mortality assumptions are based on the results obtained from a recent actual company experience study performed, which included retirees as well as other plan participants. TVA obtained an updated study in 2013, which indicated an improvement in TVA's mortality experience. Accordingly, TVA adjusted the projection period for the RP-2000 Mortality Tables for males and females projected to 2022 using scale AA at September 30, 2013. Additional experience per the actuarial review in 2014 indicated that actual experience remains in line with the assumption adopted in 2013. Therefore, TVA maintained this assumption for 2014. At September 30, 2012, the projection period for the RP- 2000 Mortality Tables for males and females was projected to 2013 using scale AA.	A 0.25 percent increase in the assumption for compensation increases would increase the 2014 projected pension benefit obligation and the 2014 net periodic pension cost by $13 million and $2 million, respectively. Discount Rate. 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. On the other hand, a lower discount rate increases net periodic pension and net periodic post-retirement benefit costs. Assuming the other components of the calculation are held constant and excluding any impact for unamortized gains or losses, a 0.25 percent decrease would increase the 2014 net periodic pension cost by $18 million and the 2014 projected pension benefit obligation by $369 million.

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Description	Judgments and Uncertainties	Effect if Actual Results Differ From Assumptions
	Health Care Cost Trends. TVA reviews actual recent cost trends and projected future trends in establishing health care cost trend rates. The assumed health care trend rates used to determine post-retirement benefit obligations for 2014 and 2013 were 7.50 percent and 8.00 percent, respectively. The 2014 health care cost trend rate of 7.50 percent used to determine post-retirement benefit obligations is assumed to gradually decrease each successive year until it reaches a 5.00 percent annual increase in health care costs in the years beginning October 1, 2019, and beyond. The assumed health care cost trend rates used to determine the net periodic post-retirement cost were 8.00 percent for 2014, 8.50 percent for 2013, and 8.00 percent for 2012. TVA plans to use 7.50 percent in the determination of 2015 net periodic post-retirement cost. TVA had increased the rate from 2012 to 2013 based upon exhibited annual increases in costs per covered life due primarily to changes in inflation, utilization, and healthcare regulations. Whereas costs in 2014 have decreased in line with the actuarial expectations as a result in plan changes and prescription drug coverage. Cost of Living Adjustment.  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. Eligible retirees receive a COLA on the base pension portion of the monthly pension benefit in January following any year in which the 12-month average Consumer Price Index for All Urban Consumers ("CPI-U") exceeded by as much as one percent the 12-month average of the CPI-U for the preceding year. The minimum COLA is one percent and the maximum is five percent. The COLA was temporarily reduced for a four-year period beginning January 1, 2010, for current retirees, and the eligibility for the COLA was changed to age 60 from attained age 55 for employees retiring on or after January 1, 2010. The COLA assumption has been 2.5 percent since 2009; however, in 2013, TVA adjusted the COLA assumption due to the Federal Reserve System’s long-term monetary policy and the market-based expectations that inflation will remain below two percent into 2015. TVA adjusted the COLA assumption at September 30, 2013 to 1.6 percent with an assumed gradual increase each successive year until it reaches 2.5 percent in 2020. At September 30, 2014, the COLA is assumed to increase to 2.0 percent with an assumed gradual increase each successive year until it reaches 2.5 percent in 2020.	Periodic post-retirement benefit cost could fluctuate if there are changes in the health care cost trend rate. Assuming that the other components of the calculation are held constant and excluding any impact for unamortized actuarial gains or losses, a one percent increase in the assumed health care cost trend rate would impact the post-retirement service and interest cost components by $7 million and the accumulated post-retirement benefit obligation by $89 million. Likewise, a one percent decrease in the health care cost trend rate would impact the post-retirement service and interest cost components by $(7) million and the accumulated post-retirement benefit obligation by $(93) million. A higher COLA assumption increases the pension benefit obligation and correspondingly increases the net periodic pension benefit cost. A lower COLA assumption decreases the pension benefit obligation and the net periodic pension benefit cost. Assuming the other components of the calculation are held constant and excluding any impact for unamortized actuarial gains or losses, a 0.25 percent increase in the COLA assumption would increase the 2014 pension benefit obligation by $250 million and increase the net periodic pension benefit cost by $28 million.

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Description	Judgments and Uncertainties	Effect if Actual Results Differ From Assumptions
	Contributions. In 2009, TVA made a contribution to TVARS of $1.0 billion for 2010 and as an advance on contributions for 2011 through 2013. In 2011, TVA made an additional discretionary contribution of $270 million to TVARS. In 2013 and 2012, the qualified defined pension plan's assets exceeded market return expectations, and no discretionary contributions were made. The minimum contribution for 2014 was $198 million; however, TVA made a $250 million contribution to TVARS. The 2015 minimum contribution is $215 million; however, TVA expects to contribute $275 million to TVARS in 2015. In 2014, TVA made contributions of $6 million to the SERP and $47 million to the other post-retirement benefit plans. TVA expects to contribute $5 million to the SERP and $39 million to the other post-retirement benefit plans in 2015.

Fair Value Measurements

Investments

Investments classified as trading consist of amounts held in the Nuclear Decommissioning Trust ("NDT"), Asset Retirement Trust ("ART"), SERP, and Long-Term Deferred Compensation Plan ("LTDCP").  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, commodities, currencies, derivative instruments, and other investments.  TVA has classified all of these trading securities as either Level 1, Level 2, or Level 3 valuations.  See Note 16 — Valuation Techniques for a discussion of valuation levels of the investments.  See Note 20 — Fair Value Measurements for disclosure of fair value measurements for investments held by TVARS that support TVA’s qualified defined benefit pension plan.

Prices provided by third-parties for the 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 which provided the price.  If the prices are validated, the primary pricing source is used.  If not, a secondary source price which 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.

In addition to the tolerance checks performed by the investment portfolio trustee, TVA 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.

Derivatives

TVA has 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 interest rate swaps are a result of the exercise of counterparty rights associated with TVA's previous swaption transactions. The swaptions were used to protect against declines in value of embedded call provisions on certain Bond issues. 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.  Prior to its conversion to an interest rate swap in April 2012, TVA had a swaption that was classified as a Level 3 valuation. The swaption was valued based on an income approach. The valuation was computed using a broker-provided pricing model utilizing interest and

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volatility rates.  The application of credit valuation adjustments ("CVAs") did not materially affect the fair value of these assets and liabilities at September 30, 2014.

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, 2014.

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 changes in prices of natural gas, fuel oil, coal, and other commodities. Although certain natural gas futures and swaps under the FTP remain at September 30, 2014, future purchases under the program have been suspended.  Management is currently evaluating the future use of financial instruments for price hedging.  TVA is prohibited from taking speculative positions in its FTP.

Financial instruments under the FTP are valued based on market approaches which utilize Chicago Mercantile Exchange ("CME") quoted prices and other observable inputs. Futures and options contracts settled on the CME are classified as Level 1 valuations. Swap contracts are valued using a pricing model based on CME inputs and are subject to nonperformance risk outside of the exit price. These contracts are classified as Level 2 valuations. The application of CVAs did not materially affect the fair value of these assets and liabilities at September 30, 2014.

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. TVA plans to continue to manage fuel price volatility through various methods, but is currently evaluating the 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, 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 2013) for companies with a similar credit rating over a time period consistent with the remaining term of the contract.

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All derivative instruments are analyzed individually and are subject to unique risk exposures.  At September 30, 2014, the aggregate counterparty credit risk adjustments applied to TVA's derivative asset and liability positions were decreases of less than $1 million and $1 million, respectively.

Collateral. TVA’s interest rate swaps, currency swaps, and commodity derivatives under the FTP 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 — Other Derivative Instruments — Collateral for a discussion of collateral related to TVA’s derivative liabilities.

New Accounting Standards and Interpretations

See Note 2 for a discussion of recent accounting standards and pronouncements which became effective for TVA during the presented periods.

Legislative and Regulatory Matters

The Fiscal Year 2014 Budget of the U.S. Government (the “Budget”) submitted to Congress contained language regarding the Administration’s intention to have the Office of Management and Budget ("OMB") undertake a strategic review of options for addressing TVA's financial situation, including the possible divestiture of TVA, in part or as a whole.

During 2014 TVA worked with OMB and other Administration officials to provide the requested information as part of the Administration’s strategic review and contracted with Lazard Frères & Co. LLC ("Lazard"), an international financial advisory and asset management firm, to assist with this review. The Lazard report recommended against divesture. OMB has not yet issued a report on its strategic review, and TVA continues to collaborate with the Administration on its ongoing strategic review.

To strengthen the Administration's efforts to increase government-wide energy efficiency and sustainability and implement goals in the President’s June 2013 Climate Action Plan, a Presidential Memorandum was issued on December 5, 2013, directing the federal government to consume 20 percent of electricity from renewable sources by 2020, to the extent economically feasible and technically practicable. TVA is on track to achieve the 2020 goal of 20 percent renewable energy use. See Item 1, Business — Environmental Matters — Executive Orders.

On April 16, 2014, the Department of Defense ("DOD") issued DOD Directive 4180.01, known as the “DOD Energy Policy”, which provides a common framework for operational energy, facilities energy, and energy-related elements of mission assurance and also establishes DOD policy to improve energy security and mitigate energy costs. The directive is based on the DOD’s decision, among other things, to place less emphasis on procuring renewable energy and more emphasis on installing renewable energy capacity on DOD installations. TVA has contracts with five military installations which represented one percent of TVA’s revenue for the years ended September 30, 2014 and September 30, 2013.

A bill has been introduced in Congress, through which Congress would approve TVA's transfer, on behalf of the United States, of the Yellow Creek Port properties to the State of Mississippi. The property was acquired to be part of a river terminal, a railroad, and industrial sites on the Pickwick Reservoir in Tishomingo County, Mississippi. The transfer would be made under Section 4(k)(b) of the TVA Act, which allows TVA to dispose of land for the purpose of erecting docks and buildings for shipping purposes or the manufacture or storage of products for the purpose of trading or shipping. Transfers under this section of the TVA Act require congressional approval. The net book value of this property was approximately $1 million at September 30, 2014.

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 of this act and its implementing regulations, 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 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.

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 Exchange Act, which requires certain issuers to disclose certain activities relating to Iran involving the issuer and its affiliates.  Based on information supplied by each such person, none of TVA's directors and executive officers are involved in any such activities.  While TVA is an agency and instrumentality of the United States of America, 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 United States.

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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 party to or otherwise involved in lawsuits, claims, proceedings, investigations, and other legal matters ("Legal Proceedings") that have arisen in the ordinary course of conducting its activities, as a result of catastrophic events or otherwise. TVA had accrued approximately $172 million with respect to Legal Proceedings at September 30, 2014. 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 21 — Legal Proceedings, which discussion is 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.  TVA plans to continue to manage fuel price volatility through various methods, but is currently evaluating the future use of financial instruments. See Note 15.

Risk Governance

The Enterprise Risk Council ("ERC") was created in 2005 to strengthen and formalize TVA's enterprise-wide risk management efforts. The 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's current members are the President and Chief Executive Officer (chair); Executive Vice President and Chief Operating Officer; Executive Vice President and Chief External Relations Officer; Executive Vice President and Chief Financial Officer; Executive Vice President and General Counsel; Senior Vice President of Human Resources and Communications; Senior Vice President of Shared Services; and Senior Vice President and Chief Risk Officer. The ERC has at times designated a representative from Office of the Inspector General to act as an advisory member.

The ERC has established a subordinate Risk Management Steering Committee ("RMSC") and a Portfolio Risk Oversight Committee ("PROC"), both of which are comprised of business unit leaders with specific expertise. The RMSC is responsible for (1) driving accountability on the mitigation of key enterprise risks, (2) promoting cross business risk collaboration and management, and (3) actively identifying emerging risks. PROC is responsible for the evaluation of TVA’s portfolio risk management processes and infrastructure for power, fuel, and other commodities critical to TVA’s power supply.    

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 the 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 RMSC, 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 previously used its FTP to help manage cost volatility for its wholesale and directly served customers.  Although management has suspended future use of financial instruments under the program, certain natural gas hedges remained in place at September 30, 2014 for the mitigation of risks associated with the price of natural gas.  A hypothetical 10 percent decline in the market price of natural gas on September 30, 2014, and 2013, would have resulted in decreases of approximately $41 million and $60 million, respectively, in the fair value of TVA’s natural gas trading derivative instruments at these dates.

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Additionally, TVA also 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, 2014, and 2013, would have resulted in decreases of approximately $109 million and $186 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, 2014, and 2013, would have resulted in decreases of approximately $26 million and $15 million, respectively, in the fair value of TVA’s natural gas derivative instruments at these dates.

Investment Price Risk

TVA’s investment price risk relates primarily to investments in TVA’s NDT, ART, pension fund, SERP, and Long-Term Deferred Compensation Plan ("LTDCP").

Nuclear Decommissioning Trust.  The NDT is generally designed to achieve a return in line with overall equity market performance.  The assets of the trust are invested in debt and equity securities, private partnerships and limited liability companies, 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, high-yield debt, domestic debt, U.S. Treasury Inflation-Protected Securities ("TIPS"), commodities, and private real estate, private equity, and absolute return strategies.  At September 30, 2014, and 2013, an immediate 10 percent decrease in the price of the investments in the trust would have reduced the value of the trust by $148 million and $132 million, respectively.  

Asset Retirement Trust.  The ART is presently invested to achieve a return in line with equity and debt market performance. The assets of the trust are invested in securities directly and indirectly through commingled funds.  At September 30, 2014, and 2013, an immediate 10 percent decrease in the price of the investments in the trust would have reduced the value of the trust by $40 million and $34 million, respectively.

Qualified Pension Plan. TVARS has a long-term investment plan which contains a dynamic de-risking strategy that allocates investments to assets that better match the liability, such as long duration fixed income securities, over time as funding status targets are met. The current investment asset allocation policy approved by the TVARS Board has targets of 47 percent equity including U.S., non-U.S., private, and low volatility global public equity investments, 28 percent fixed income securities, 15 percent public real assets including TIPS, commodities, and Master Limited Partnerships ("MLPs"), and 10 percent private real assets. The qualified pension plan assets are invested across global public equity, private equity, cash, core fixed income, long- term core fixed income, investment grade credit, high yield fixed income, emerging markets fixed income, global TIPS, commodities, MLPs, and private real assets. The TVARS asset allocation policy includes permissible deviations from these target allocations. The TVARS Board can take action, as appropriate, to rebalance the system’s assets consistent with the asset allocation policy. At September 30, 2014, and 2013, 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 $751 million and $722 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 a limited number of executives. 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 65 percent equity securities, which includes U.S. and non-U.S. equities, and 35 percent fixed income securities. The SERP plan assets are presently invested to achieve a return in line with overall equity market performance. At September 30, 2014, and 2013, an immediate 10 percent decrease in the value of the SERP investments would have reduced the value by $5 million.

Long-Term Deferred Compensation Plan. The LTDCP is designed to provide long-term incentives to executives to encourage them to stay with TVA and to provide competitive levels of total compensation to such executives. 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 include long-term deferred compensation and any other deferred 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 September 30, 2014, and 2013, an immediate 10 percent decrease in the value of the deferred compensation accounts would have reduced the value by $5 million and $6 million, respectively.

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.

Short-Term Investments.  At September 30, 2014, TVA had $500 million of cash and cash equivalents, and the average balance of cash and cash equivalents for 2014 was $755 million.  The average interest rate that TVA received on its short-term investments during 2014 was less than one percent.  If the rates of interest that TVA received on its short-term investments during 2014 were zero percent, TVA would have received less than $1 million less in interest from its short-term investments during 2014.  At September 30, 2013, TVA had $1.6 billion of cash and cash equivalents, and the average balance of cash and

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cash equivalents for 2013 was $1.0 billion.  The average interest rate that TVA received on its short-term investments during 2013 was less than one percent.  If the rates that TVA received on its short-term investments during 2013 were zero percent, TVA would have received $1 million less in interest on short-term investments during 2013.  In addition to affecting the amount of interest that TVA receives from its short-term investments, changes in interest rates could affect the value of the investments in its pension plan, ART, NDT, and SERP.  See Risk Management Activities — Investment Price Risk.

Short-Term Debt.  At September 30, 2014, TVA’s short-term borrowings were $596 million, and the current maturities of long-term debt were $1.1 billion.  Based on TVA’s interest rate exposure at September 30, 2014, an immediate one percentage point increase in interest rates would have resulted in an increase of $17 million in TVA’s short-term interest expense.  At September 30, 2013, TVA’s short-term borrowings were $2.4 billion, and the current maturities of long-term debt were $62 million.  Based on TVA’s interest rate exposure at September 30, 2013, an immediate one percentage point increase in interest rates would have resulted in an increase of $25 million in TVA’s short-term interest expense.

Long-Term Debt.  At September 30, 2014, and 2013, 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 this debt by issuing additional long-term debt.  Accordingly, if interest rates are high when TVA issues this additional long-term 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, 2014, and 2013, the average life of TVA’s debt portfolio was 16.6 years and 17.8 years, respectively.  A schedule of TVA’s debt maturities is contained in Note 13 — Debt Outstanding.

Interest Rate Derivatives. Changes in interest rates also affect the mark-to-market valuation of TVA’s interest rate derivatives.  TVA had four interest rate swaps outstanding at September 30, 2014 and September 30, 2013. 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, 2014, an immediate one-half percentage point decrease in interest rates would have increased the interest rate swap liabilities by $237 million.  Based on TVA’s interest rate exposure at September 30, 2013, an immediate one-half percentage point decrease in interest rates would have increased the interest rate swap liabilities by $220 million.

Currency Exchange Rate Risk

At September 30, 2014, and 2013, TVA had three issues of Bonds outstanding whose principal and interest payments were denominated in British pounds sterling.  TVA issued these Bonds in amounts of £200 million, £250 million, and £150 million in 1999, 2001, and 2003, respectively.  When TVA issued these Bonds, it hedged its currency exchange rate risk by entering into currency swap agreements.  Accordingly, at September 30, 2014, and 2013, a 10 percent change in the British pound sterling-U.S. dollar exchange rate would not have had a material impact on TVA’s cash flows, results of operations, or financial position as these instruments are completely hedged.

Counterparty Credit Risk

Counterparty credit risk is the exposure to economic loss that would occur as a result of a counterparty’s nonperformance of its contractual obligations.  Where exposed to counterparty credit 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 employs credit mitigation measures, such as collateral or prepayment arrangements and master purchase and sale agreements, to mitigate credit risk.

Credit of Customers.  The majority of TVA’s counterparty credit risk is limited to trade accounts receivable from delivered power sales to LPCs, all located in the Tennessee Valley region.  To a lesser extent, TVA is exposed to credit risk from industries and federal agencies directly served and 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 had concentrations of accounts receivable from three customers that represented 27 percent of total accounts receivable at September 30, 2014 and 2013.  

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The table below summarizes TVA’s customer credit risk from trade accounts receivable at September 30, 2014 and 2013:

Customer Credit Risk At September 30
	2014		2013
Trade accounts receivable (1)
Investment grade
Local power companies	$	798	$	756
Exchange power arrangements	1		2
Industries and federal agencies directly served	49		51
Internally rated - investment grade
Local power companies	704		661
Exchange power arrangements	1		3
Industries and federal agencies directly served	9		8
Non-investment grade
Industries and federal agencies directly served	4		3
Internally rated - non-investment grade
Exchange power arrangements	3		3
Industries and federal agencies directly served	7		8
Total trade accounts receivable	1,576		1,495
Other accounts receivable
Miscellaneous accounts	95		73
Provision for uncollectible accounts	—		(1		)
Total other accounts receivable	95		72
Accounts receivable, net	$	1,671	$	1,567

Note

(1)  Includes unbilled power receivables of $19 million and $15 million at September 30, 2014 and September 30, 2013, respectively.

Counterparty Performance Risk. In addition to being exposed to economic loss due to the nonperformance of TVA’s customers, TVA is exposed to economic loss because of the nonperformance of its other counterparties, including suppliers and counterparties to its derivative contracts.  Where exposed to performance risk, TVA analyzes the counterparty’s financial condition prior to entering into an agreement and employs performance assurance measures, such as parent guarantees, letters of credit, cash deposits, or performance bonds, to mitigate the risk.

TVA has various agreements under which it has exposure to various financial institutions with which it does business.  Most of these are not material on a net exposure basis.  TVA believes its policies and procedures for counterparty performance risk reviews have generally protected TVA against significant exposure to financial institutions impacted by recent market and economic conditions.

Credit of 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 money that it paid to the supplier under the contract and have to purchase replacement fuel or power on the spot market, perhaps at a significantly higher price than TVA was entitled to pay under the contract.  In addition, TVA might not be able to acquire replacement fuel or power in a timely manner and thus might be unable to satisfy its own obligations to deliver power.  TVA has a power purchase agreement with a supplier that expires on March 31, 2032.  TVA has determined that the supplier has the equivalent of a non-investment grade credit rating.  As a result of the supplier’s credit ratings, the company has provided credit assurance to TVA under the terms of its agreement.

Credit of Derivative Counterparties.  TVA has entered into derivative contracts for hedging purposes, and TVA’s NDT and qualified pension plan have entered into derivative contracts for investment purposes.  If a counterparty to one of TVA’s hedging transactions defaults, TVA might incur substantial costs in connection with entering into a replacement hedging transaction.  If a counterparty to the derivative contracts into which the NDT and the qualified pension plan have entered for investment purposes defaults, the value of the investment could decline significantly, or perhaps become worthless.

Credit of TVA

A downgrade in TVA's credit rating could have material adverse effects on TVA's cash flows, results of operations, and financial condition and could harm investors in TVA securities. Among other things, a downgrade could have the following effects:

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• A downgrade could increase TVA’s interest expense by increasing the interest rates that TVA pays on new Bonds that it issues.  An increase in TVA’s interest expense 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 could result in TVA's having to post additional collateral under certain physical and financial contracts that contain rating triggers.  

• A downgrade below a contractual threshold could prevent TVA from borrowing under three credit facilities totaling $2.5 billion.

• A downgrade could lower the price of TVA securities in the secondary market, thereby hurting investors who sell TVA securities after the downgrade and diminishing the attractiveness and marketability of TVA Bonds.

For a discussion of risk factors related to TVA’s credit rating, see Item 1A, Risk Factors.

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 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 BALANCE SHEETS

At September 30

 (in millions)

ASSETS
	2014			2013
Current assets
Cash and cash equivalents	$	500		$	1,602
Restricted cash and investments	19			33
Accounts receivable, net	1,676			1,567
Inventories, net	1,056			1,091
Regulatory assets	481			561
Other current assets	56			52
Total current assets	3,788			4,906
Property, plant, and equipment
Completed plant	47,564			47,073
Less accumulated depreciation	(24,589		)	(23,157		)
Net completed plant	22,975			23,916
Construction in progress	5,951			4,704
Nuclear fuel	1,322			1,256
Capital leases	102			47
Total property, plant, and equipment, net	30,350			29,923
Investment funds	1,981			1,701
Regulatory and other long-term assets
Regulatory assets	8,994			9,131
Other long-term assets	483			445
Total regulatory and other long-term assets	9,477			9,576
Total assets	$	45,596		$	46,106
The accompanying notes are an integral part of these consolidated financial statements.

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TENNESSEE VALLEY AUTHORITY

 CONSOLIDATED BALANCE SHEETS

At September 30

 (in millions)

LIABILITIES AND PROPRIETARY CAPITAL
	2014		2013
Current liabilities
Accounts payable and accrued liabilities	$	2,029	$	1,627
Environmental cleanup costs - Kingston ash spill	21		102
Accrued interest	380		378
Current portion of leaseback obligations	75		69
Current portion of energy prepayment obligations	100		100
Regulatory liabilities	184		212
Short-term debt, net	596		2,432
Current maturities of power bonds	1,032		32
Current maturities of long-term debt of variable interest entities	32		30
Total current liabilities	4,449		4,982
Other liabilities
Post-retirement and post-employment benefit obligations	5,839		5,348
Asset retirement obligations	3,089		3,472
Other long-term liabilities	1,962		1,861
Leaseback obligations	616		692
Energy prepayment obligations	310		410
Environmental cleanup costs - Kingston ash spill	—		67
Regulatory liabilities	—		1
Total other liabilities	11,816		11,851
Long-term debt, net
Long-term power bonds, net	21,948		22,315
Long-term debt of variable interest entities	1,279		1,311
Total long-term debt, net	23,227		23,626
Total liabilities	39,492		40,459
Commitments and contingencies (Note 21)
Proprietary capital
Power program appropriation investment	258		268
Power program retained earnings	5,240		4,767
Total power program proprietary capital	5,498		5,035
Nonpower programs appropriation investment, net	601		609
Accumulated other comprehensive income (loss)	5		3
Total proprietary capital	6,104		5,647
Total liabilities and proprietary capital	$	45,596	$	46,106
The accompanying notes are an integral part of these consolidated financial statements.

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  TENNESSEE VALLEY AUTHORITY

 CONSOLIDATED STATEMENTS OF OPERATIONS

For the years ended September 30

 (in millions)

	2014			2013			2012
Operating revenues
Revenue from sales of electricity	$	10,999		$	10,829		$	11,086
Other revenue	138			127			134
Total operating revenues	11,137			10,956			11,220
Operating expenses
Fuel	2,730			2,820			2,680
Purchased power	1,094			1,027			1,189
Operating and maintenance	3,341			3,428			3,510
Depreciation and amortization	1,843			1,680			1,919
Tax equivalents	540			548			622
Total operating expenses	9,548			9,503			9,920
Operating income	1,589			1,453			1,300
Other income (expense), net	49			44			33
Interest expense
Interest expense	1,344			1,394			1,444
Allowance for funds used during construction and nuclear fuel expenditures	(175		)	(168		)	(171		)
Net interest expense	1,169			1,226			1,273
Net income (loss)	$	469		$	271		$	60
The accompanying notes are an integral part of these consolidated financial statements.

  TENNESSEE VALLEY AUTHORITY

 CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

For the years ended September 30

(in millions)

	2014			2013			2012
Net income (loss)	$	469		$	271		$	60
Other comprehensive income (loss)
Net unrealized gain (loss) on cash flow hedges	4			78			99
Reclassification to earnings from cash flow hedges	(2		)	(1		)	(35		)
Total other comprehensive income (loss)	$	2		$	77		$	64
Total comprehensive income (loss)	$	471		$	348		$	124
The accompanying notes are an integral part of these consolidated financial statements.

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TENNESSEE VALLEY AUTHORITY

 CONSOLIDATED STATEMENTS OF CASH FLOWS

 For the years ended September 30

 (in millions)

	2014			2013			2012
Cash flows from operating activities
Net income (loss)	$	469		$	271		$	60
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation and amortization (including amortization of debt issuance costs and premiums/discounts)	1,888			1,723			1,947
Amortization of nuclear fuel cost	279			268			264
Non-cash retirement benefit expense	572			622			607
Prepayment credits applied to revenue	(100		)	(102		)	(105		)
Fuel cost adjustment deferral	(38		)	97			(61		)
Fuel cost tax equivalents	6			2			47
Environmental cleanup costs – Kingston ash spill – non cash	68			72			73
Changes in current assets and liabilities
Accounts receivable, net	(79		)	114			89
Inventories and other current assets, net	34			27			(131		)
Accounts payable and accrued liabilities	147			(296		)	60
Accrued interest	2			1			(26		)
Regulatory assets costs	(56		)	(21		)	(14		)
Pension contributions	(256		)	(6		)	(8		)
Environmental cleanup costs – Kingston ash spill	(109		)	(99		)	(108		)
Insurance recoveries	175			47			5
Other, net	(22		)	(123		)	(125		)
Net cash provided by operating activities	2,980			2,597			2,574
Cash flows from investing activities
Construction expenditures	(2,384		)	(2,051		)	(2,119		)
Nuclear fuel expenditures	(326		)	(287		)	(361		)
Purchases of investments, net	(48		)	(48		)	(48		)
Loans and other receivables
Advances	(6		)	(6		)	(2		)
Repayments	6			9			10
Other, net	2			(2		)	7
Net cash used in investing activities	(2,756		)	(2,385		)	(2,513		)
Cash flows from financing activities
Long-term debt
Issues of power bonds	989			2,122			1,126
Issues of variable interest entities	—			360			1,000
Redemptions and repurchases of power bonds	(365		)	(2,358		)	(2,717		)
Payments on debt of variable interest entities	(30		)	(13		)	(6		)
Short-term debt issues (redemptions), net	(1,837		)	924			1,024
Payments on leases and leasebacks	(73		)	(446		)	(84		)
Proceeds from call monetization	—			—			60
Financing costs, net	(4		)	(20		)	(75		)
Payments to U.S. Treasury	(14		)	(27		)	(27		)
Other, net	8			(20		)	(1		)
Net cash (used in) provided by financing activities	(1,326		)	522			300
Net change in cash and cash equivalents	(1,102		)	734			361
Cash and cash equivalents at beginning of year	1,602			868			507
Cash and cash equivalents at end of year	$	500		$	1,602		$	868
The accompanying notes are an integral part of these consolidated financial statements.

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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)from Net Gains (Losses) on Cash Flow Hedges			Total
Balance at September 30, 2011	$	308		$	4,429		$	630		$	(138	)	$	5,229
Net income (loss)	—			70			(10		)	—			60
Total other comprehensive income (loss)	—			—			—			64			64
Return on power program appropriation investment	—			(7		)	—			—			(7		)
Return of power program appropriation investment	(20		)	—			—			—			(20		)
Balance at September 30, 2012	$	288		$	4,492		$	620		$	(74	)	$	5,326
Net income (loss)	—			282			(11		)	—			271
Total other comprehensive income (loss)	—			—			—			77			77
Return on power program appropriation investment	—			(7		)	—			—			(7		)
Return of power program appropriation investment	(20		)	—			—			—			(20		)
Balance at September 30, 2013	$	268		$	4,767		$	609		$	3		$	5,647
Net income (loss)	—			477			(8		)	—			469
Total other comprehensive income (loss)	—			—			—			2			2
Return on power program appropriation investment	—			(4		)	—			—			(4		)
Return of power program appropriation investment	(10		)	—			—			—			(10		)
Balance at September 30, 2014	$	258		$	5,240		$	601		$	5		$	6,104
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	87
2	Impact of New Accounting Standards and Interpretations	93
3	Restructuring	94
4	Accounts Receivable, Net	94
5	Inventories, Net	95
6	Net Completed Plant	95
7	Other Long-Term Assets	96
8	Regulatory Assets and Liabilities	96
9	Variable Interest Entities	99
10	Kingston Fossil Plant Ash Spill	101
11	Other Long-Term Liabilities	102
12	Asset Retirement Obligations	102
13	Debt and Other Obligations	103
14	Accumulated Other Comprehensive Income (Loss)	108
15	Risk Management Activities and Derivative Transactions	108
16	Fair Value Measurements	115
17	Proprietary Capital	122
18	Other Income (Expense), Net	123
19	Supplemental Cash Flow Information	123
20	Benefit Plans	123
21	Commitments and Contingencies	138
22	Related Parties	144
23	Unaudited Quarterly Financial Information	145

1.  Summary of Significant Accounting Policies

General

The Tennessee Valley Authority ("TVA") is a corporate agency and instrumentality of the United States that was created in 1933 by legislation enacted by the United States ("U.S.") Congress 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 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 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 over nine 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 ("Bonds").  Although TVA does not currently receive congressional appropriations, it is required to make annual payments to the U.S. Treasury as a return on the government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment").  In the 1998 Energy and Water Development Appropriations Act, Congress directed TVA to fund essential stewardship activities related to its management of the Tennessee River system and nonpower or stewardship properties with power revenues in the event that there were insufficient appropriations or other available funds to pay for such activities in any fiscal year.  Congress has not provided any appropriations to TVA to fund such activities since 1999.  Consequently, during 2000, TVA began paying for essential stewardship activities primarily with power

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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 ("TVA Board") as authorized by the Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (as amended, 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 power system assets, retirement of outstanding Bonds in advance of maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected with TVA's power business.  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 (2014, 2013, 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.  In view of demand for electricity and the level of competition, 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 and variable interest entities of which TVA is determined to be the primary beneficiary. See Note 9. 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 reclassifications have been made to the Consolidated Statement of Cash Flows for the year ended September 30, 2014, in the Cash flows from operating activities section as $47 million and $5 million previously reported in Environmental cleanup costs — Kingston ash spill for the years ended September 30, 2013 and 2012, respectively, were reclassified to Insurance recoveries.    

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Cash and Cash Equivalents

Cash includes cash on hand and non-interest bearing cash and deposit accounts. All highly liquid investments with original maturities of three months or less are considered cash equivalents.

Restricted Cash and Investments

Restricted cash and investments reflect amounts related to collateral posted with TVA by a swap counterparty.

Allowance for Uncollectible Accounts

The allowance for uncollectible accounts reflects TVA's estimate of probable losses inherent in its accounts and loans receivable balances.  TVA determines the allowance based on known accounts, historical experience, and other currently available information including events such as customer bankruptcy and/or a customer 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 $1 million at September 30, 2014, and 2013, for accounts receivable.  Additionally, loans receivable of $92 million and $73 million at September 30, 2014, and 2013, respectively, were included in Accounts receivable, net and Other long-term assets and reported net of allowances for uncollectible accounts of $9 million and $10 million at September 30, 2014, and 2013, respectively.

The following table contains information about TVA’s current estimates related to uncollectible accounts.

Allowance for Uncollectible Accounts (in millions)
Description	Balance at beginning of year		Additions charged to expense		Deductions			Balance at end of year
For the year ended September 30, 2014
Allowance for uncollectible accounts
Receivables	$	1	$	1	$	(1	)	$	1
Loans	10		—		(1		)	9
Total allowances deducted from assets	$	11	$	1	$	(2	)	$	10
For the year ended September 30, 2013
Allowance for uncollectible accounts
Receivables	$	7	$	—	$	(6	)	$	1
Loans	12		—		(2		)	10
Total allowances deducted from assets	$	19	$	—	$	(8	)	$	11
For the year ended September 30, 2012
Allowance for uncollectible accounts
Receivables	$	1	$	6	$	—		$	7
Loans	11		1		—			12
Total allowances deducted from assets	$	12	$	7	$	—		$	19

Revenues

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 six 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.) 

From time to time TVA transfers fiber optic capacity on TVA’s network to telecommunications service carriers and local power company customers of TVA ("LPCs").  These transactions are structured as indefeasible rights of use ("IRUs"), which are

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the exclusive right to use a specified amount of fiber optic capacity for a specified term.  TVA accounts for the consideration received on transfers of fiber optic capacity for cash and on all of the other elements deliverable under an IRU as revenue ratably over the term of the agreement.  TVA does not recognize revenue on any contemporaneous exchanges of its fiber optic capacity for an IRU of fiber optic capacity of the counterparty to the exchange.

TVA engages in a wide array of arrangements in addition to power sales.  TVA records revenue when it is realized or realizable and earned when all of the following criteria are met: persuasive evidence of an arrangement exists; delivery has occurred or services have been rendered; the price or fee is fixed or determinable; and collectability is reasonably assured. Revenues from activities related to TVA’s overall mission are recorded as other operating revenue versus those that are not related to the overall mission, which are recorded in Other income (expense), net.

Inventories

CertainFuel, Materials, and Supplies.  Coal, oil, limestone, tire-based fuel inventories, and 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. Natural gas inventories are valued using an average cost method, and a new average cost is computed monthly.

Allowance for Inventory Obsolescence.  TVA reviews material 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.  Based on the estimated value of the inventory, TVA adjusts its allowance for inventory obsolescence.

Emission Allowances.  TVA has emission allowances for sulfur dioxide ("SO₂")and nitrogen oxides ("NO_x") which are accounted for as inventory.  The average cost of allowances used each month is charged to operating expense based on tons of SO₂ and NO_x emitted during the respective compliance periods.  Allowances granted to TVA by the Environmental Protection Agency ("EPA") are recorded at zero cost.

Property, Plant, and Equipment, and Depreciation

Property, Plant, and Equipment. Additions to plant are recorded at cost, which includes direct and indirect costs and an allowance for funds used during construction ("AFUDC").  The cost of current repairs and minor replacements is charged to operating expense.  Nuclear fuel inventories, which are included in Property, plant, and equipment, are 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.

Depreciation. TVA accounts for depreciation of its properties using the composite depreciation convention of accounting.  Accordingly, the original cost of property retired is charged to accumulated depreciation. Except as described below, depreciation is generally computed on a straight-line basis over the estimated service lives of the various classes of assets. Depreciation expense for the years ended September 30, 2014, 2013, and 2012 was $1.6 billion, $1.4 billion, and $1.7 billion, respectively. Depreciation expense expressed as a percentage of the average annual depreciable completed plant was 3.42 percent for 2014, 3.12 percent for 2013, and 3.78 percent for 2012.  Average depreciation rates by asset class are as follows:

Property, Plant, and Equipment Depreciation Rates At September 30 (percent)
	2014	2013	2012
Asset Class
Nuclear	2.90	2.86	2.71
Coal-Fired	4.37	3.47	5.65
Hydroelectric	1.44	1.30	1.35
Gas and oil-fired	3.23	3.21	3.67
Transmission	2.76	2.76	2.99
Other	8.40	8.14	8.10

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 (collectively, the "Environmental Agreements”).  See Note 21 — Legal Proceedings — Environmental Agreements.  Under the Environmental Agreements, TVA committed, among other things, to retire, on a phased schedule, 18 coal-fired units. 

Consistent with the Environmental Agreements, Units 1 and 2 at John Sevier Fossil Plant ("John Sevier") were retired

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on December 31, 2012, and Units 3 and 4 were idled on December 31, 2012 and subsequently retired on June 25, 2014. Units 3 and 5 at Widows Creek Fossil Plant ("Widows Creek") were retired on July 31, 2013, and Units 1, 2, 4, and 6 at Widows Creek were retired on July 31, 2014. On October 1, 2013, Colbert Fossil Plant ("Colbert") Unit 5 and Johnsonville Fossil Plant ("Johnsonville") Units 5, 6, 9, and 10 were idled. In addition, Units 7 and 8 at Johnsonville were idled March 1, 2012, and Unit 10 at Shawnee Fossil Plant ("Shawnee") was idled in October 2010 and subsequently retired on June 30, 2014.

On November 14, 2013, the TVA Board of Directors (the "TVA Board") approved the retirement of Colbert Units 1-5 no later than June 30, 2016, and the retirement of Widows Creek Unit 8. Additionally, the TVA Board approved the retirement of Paradise Fossil Plant ("Paradise") Units 1 and 2 upon the completion of a natural gas-fired plant at the Paradise location.

On August 21, 2014, the TVA Board approved the retirement of Allen Fossil Plant ("Allen") Units 1-3 upon the completion of a natural gas-fired plant at the Allen location.

Depreciation rates are adjusted to reflect current assumptions so that the units will be fully depreciated by the applicable idle dates.  As a result of TVA's decision to idle or retire units, TVA recognized $206 million and $49 million in accelerated depreciation expense related to the units during the years ended September 30, 2014, and 2013, respectively.

Capital Lease Agreements.  Property, plant, and equipment also includes assets recorded under capital lease agreements. These primarily consist of a natural gas lateral pipeline, power production facilities, water treatment assets, and land of $102 million and $42 million at September 30, 2014 and 2013, respectively, and fuel fabrication and blending facilities of $5 million at September 30, 2013. There were no obligations for fuel fabrication and blending facilities at September 30, 2014. Amortization expense related to capital leases is included in Depreciation and amortization in TVA’s statements of operations.

Allowance for Funds Used During Construction.  AFUDC capitalized during the year ended September 30, 2014, was $175 million, as compared to $168 million capitalized during the year ended September 30, 2013.  TVA capitalizes interest as AFUDC, based on the average interest rate of TVA’s outstanding debt.  The allowance is applicable to construction in progress related to projects with (1) an expected total project cost of $1.0 billion or more, and (2) an estimated construction period of at least three years in duration. During 2012 and 2011, TVA also included certain nuclear fuel inventories in the calculation of the allowance. During 2012, the TVA Board approved a change in the AFUDC methodology which removed the inclusion of nuclear fuel from the AFUDC calculation effective October 1, 2012. The accumulated balance of costs, which is used to calculate AFUDC, averaged approximately $3.3 billion for the year ended September 30, 2014. Subsequent to August 31, 2013, the accumulated balance of costs for Bellefonte Nuclear Plant ("Bellefonte") were removed from this calculation.

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 amortized primarily over five years.  At September 30, 2014 and 2013, unamortized computer software costs totaled $22 million and $5 million, respectively.  Amortization expense related to capitalized computer software costs was $31 million for each of 2014, 2013, and 2012.  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, 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 Board approval, reclassified as a regulatory asset.

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 reclamation.  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.  Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset.  See Note 8 — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs andNote 12.

Blended Low-Enriched Uranium Program

Under the blended low-enriched uranium ("BLEU") program, TVA, the 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

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other uranium down to a level that allows the blended uranium to be fabricated into fuel that can be used in nuclear power plants.  This blended nuclear fuel was first loaded in a Browns Ferry Nuclear Plant ("Browns Ferry") reactor in 2005 and is expected to continue to be used to reload the Browns Ferry reactors through at least 2016. BLEU fuel was loaded into Sequoyah Nuclear Plant ("Sequoyah") Unit 2 three times but is not expected to be used in the Sequoyah reactors in the future.

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.  The third-party fuel processors own the conversion and processing facilities and will retain title to all land, property, plant, and equipment used in the BLEU fuel program.  Over the life of the program, TVA projects that the DOE’s share of savings generated by TVA’s use of this blended nuclear fuel could result in payments to the DOE of as much as $160 million.  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.  During 2009, the DOE and TVA agreed that this obligation would be offset by amounts that the DOE expects to owe TVA in the future for certain decommissioning costs that TVA will pay on the DOE’s behalf.  Accordingly, TVA will remit the BLEU fuel savings amounts to the DOE, only after those future decommissioning costs have been offset against TVA’s obligation to the DOE. At September 30, 2014, TVA had paid out approximately $101 million for this program, and the obligation recorded was $16 million.

Investment Funds

Investment funds consist primarily of trust funds designated to fund nuclear decommissioning requirements (see Note 21 — Contingencies — Decommissioning Costs), non-nuclear AROs (see Note 8 — Non-Nuclear Decommissioning Costs), the Supplemental Executive Retirement Plan ("SERP") (see Note 20 — Overview of Plans and Benefits — Supplemental Executive Retirement Plan), and the Long-Term Deferred Compensation Plan ("LTDCP"). Nuclear decommissioning funds and SERP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity market performance, while asset retirement and LTDCP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity and debt market performance. The nuclear decommissioning funds, asset retirement funds, SERP funds, and LTDCP funds are all classified as trading.

Energy Prepayment Obligations and Discounts on Sales

During 2002, TVA introduced an energy prepayment program, the discounted energy units ("DEU") program.  Under this program, TVA LPCs could purchase DEUs generally in $1 million increments, and each DEU entitles the purchaser to a $.025/kilowatt-hour discount on a specified quantity of firm power over a period of years (5, 10, 15, or 20) for each kilowatt-hour in the prepaid block.  The remainder of the price of the kilowatt-hours delivered to the LPC is due upon billing.  TVA’s DEU program allowed LPCs to use cash on hand to prepay TVA for some of their power needs, providing funding to TVA and a savings to LPCs in the form of a discount on future purchases.  The LPC receives a discount on a specified volume of firm energy purchased.  The supplement to the power contract specifies the discount rate (2.5 cents per kilowatt-hour), the monthly block of kilowatt-hours to which the discount applies, the number of years (term), and contingencies upon contract termination.

TVA has not offered the DEU program since the end of 2004.  Total sales for the program since inception have been approximately $55 million.  TVA accounted for the prepayment proceeds as unearned revenue and reported the obligations to deliver power as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2013 Consolidated Balance Sheet. There were no outstanding DEU liabilities at September 30, 2014.

TVA recognizes revenue as electricity is delivered to LPCs, based on the ratio of units of kilowatt-hours delivered to total units of kilowatt-hours under contract.  At September 30, 2014, all of TVA’s obligations under the DEU program had expired, and the entire approximately $55 million had been applied against power billings on a cumulative basis during the life of the program, of which less than $1 million was recognized as noncash revenue during 2014.  Approximately $2 million and $5 million were applied against power billings during 2013 and 2012, respectively.

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 is reporting the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2014 and 2013 Consolidated Balance Sheets.  TVA expects to recognize approximately $100 million of noncash revenue in each year of the arrangement as electricity is delivered to MLGW based on the ratio of units of kilowatt-hours delivered to total units of kilowatt-hours under contract.  At September 30, 2014, approximately $1.1 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 during each of 2014, 2013, and 2012.

Discounts, which are recorded as a reduction to electricity sales, for both programs amounted to $46 million for the year ended September 30, 2014, and $47 million for each of the years ended September 30, 2013, and 2012.

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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 balance sheets.

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.

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.

TVA purchases nuclear liability insurance, nuclear property, decommissioning, and decontamination insurance, and nuclear accidental outage insurance.  See Note 21— Contingencies — Nuclear Insurance.

TVA purchases excess liability insurance for aviation, auto, marine, and general liability exposures.  TVA purchases property insurance for certain conventional (non-nuclear) assets.  

The insurance policies are subject to the terms and conditions of the specific policy.  Each of the insurance policies purchased contains deductibles or self-insured retentions.  TVA recovers the costs of losses 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

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 and then adds 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 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 accounting standards became effective for TVA on October 1, 2013.

Balance Sheet. In December 2011, the Financial Accounting Standards Board ("FASB") issued guidance that requires additional disclosures relating to the rights of offset or other netting arrangements of assets and liabilities that are presented on a net or gross basis in the consolidated balance sheets. In January 2013, FASB issued additional guidance to limit the scope of the new offsetting disclosure requirements to derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and lending transactions.  The guidance requires the disclosure of the gross amounts subject to offset, actual amounts offset in accordance with GAAP, and the related net exposure. These changes became effective for TVA on October 1, 2013, and have been applied on a retrospective basis. This guidance relates solely to enhanced disclosures in the notes to the consolidated financial statements and did not have an impact on TVA's financial condition, results of operations, or cash flows.

Comprehensive Income. In February 2013, FASB issued guidance that requires public reporting companies under the Securities Act of 1933 to present information about reclassification adjustments from accumulated other comprehensive income (loss) ("AOCI") in their annual and interim financial statements in a single location. The guidance requires that companies present the effect of significant amounts reclassified from each component of AOCI based on its source and the income statement line items affected by the reclassification. This information may be disclosed either in a single note or parenthetically on the face of the financial statements. If a component is not required to be reclassified to net income in its entirety, companies must cross reference to the related footnote for additional information. These changes became effective for TVA on October 1,

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2013, and have been applied on a prospective basis. TVA has chosen to disclose the required information in a single note. This guidance relates solely to enhanced disclosures and did not have an impact on TVA's financial condition, results of operations, or cash flows.

The following accounting standards have been issued, but as of September 30, 2014, were not effective and had not been adopted by TVA.

Revenue Recognition.  In May 2014, FASB issued a new revenue recognition standard that applies to revenue from contracts with customers. The standard requires that an entity recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  The standard becomes effective for TVA on October 1, 2017, and allows for either a full retrospective or a modified retrospective application.  Early adoption of the standard is not permitted. TVA is currently evaluating the potential impact of these changes on its consolidated financial statements and related disclosures and the application method to be used.

Liabilities. In February 2013, FASB issued ASU 2013-04, "Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date," which defines how entities measure obligations from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date and for which no guidance exists, except for obligations addressed within existing guidance in GAAP. The guidance also requires entities to disclose the nature and amount of the obligation as well as other information about those obligations. The standard becomes effective for TVA on October 1, 2014. Retrospective presentation for all comparative periods presented is required and early adoption is permitted. TVA has evaluated the impact of adopting this guidance and expects no material impact on TVA's financial condition, results of operations, or cash flows.

3.  Restructuring

TVA is undertaking cost reduction initiatives with the goal of keeping rates low, keeping reliability high, and continuing to fulfill its broader mission of environmental stewardship and economic development. TVA’s current focus is on reducing operating and maintenance costs through further efficiency gains and streamlining the organization. The goal is to reduce TVA’s operating and maintenance costs by $500 million by 2015 as compared to its 2013 budget. As part of these cost reduction initiatives, an organizational restructuring occurred in 2014, which resulted in approximately 2,000 position reductions achieved through attrition, elimination of vacant positions, and employees leaving TVA either voluntarily or involuntarily. Certain employees were eligible for severance payments as a result of these cost reduction initiatives. Remaining amounts to be paid are included in Accounts payable and accrued liabilities on the Consolidated Balance Sheets and the 2014 restructuring expense is included in Operating and maintenance on the Consolidated Statements of Operations. The table below summarizes the activity related to severance costs:

Severance Cost Liability For the year ended September 30
	2014
Severance cost liability at beginning of period	$	—
Liabilities incurred during the period	65
Actual costs paid during the period	(20		)
Severance cost liability at end of period	$	45

4.  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
	2014			2013
Power receivables	$	1,576		$	1,495
Other receivables	101			73
Allowance for uncollectible accounts	(1		)	(1		)
Accounts receivable, net	$	1,676		$	1,567

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5.  Inventories, Net

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

Inventories, Net At September 30
	2014			2013
Materials and supplies inventory	$	616		$	620
Fuel inventory	473			494
Emission allowance inventory	13			14
Allowance for inventory obsolescence	(46		)	(37		)
Inventories, net	$	1,056		$	1,091

6. Net Completed Plant

Net completed plant consisted of the following:

Net Completed Plant At September 30
	2014						2013
	Cost		Accumulated Depreciation		Net		Cost		Accumulated Depreciation		Net
Coal-fired	$	14,078	$	9,065	$	5,013	$	13,847	$	8,429	$	5,418
Gas and oil-fired	3,411		1,094		2,317		3,386		1,008		2,378
Nuclear	18,489		9,593		8,896		18,725		9,103		9,622
Transmission	6,519		2,683		3,836		6,300		2,562		3,738
Hydroelectric	2,547		889		1,658		2,392		892		1,500
Other electrical plant	1,550		885		665		1,452		792		660
Subtotal	46,594		24,209		22,385		46,102		22,786		23,316
Multipurpose dams	928		364		564		928		356		572
Other stewardship	42		16		26		43		15		28
Subtotal	970		380		590		971		371		600
Total	$	47,564	$	24,589	$	22,975	$	47,073	$	23,157	$	23,916

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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
	2014		2013
EnergyRight® receivables	$	123	$	117
Unamortized debt issue cost of power bonds	68		75
Loans and other long-term receivables, net	87		73
Coal contract derivative assets	—		1
Prepaid capacity payments	58		62
Currency swap assets, net	—		28
Restricted cash	64		—
Other	83		89
Total other long-term assets	$	483	$	445

In association with the EnergyRight^® Solutions program, LPCs offer financing to end-use customers for the purchase of energy-efficient equipment. 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 loan 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. As of September 30, 2014 and September 30, 2013, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was approximately $33 million. See Note 11 for information regarding the associated financing obligation.     

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. 

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Regulatory Assets and Liabilities At September 30
	2014		2013
Current regulatory assets
Unrealized losses on commodity derivatives	$	134	$	183
Deferred nuclear generating units	237		237
Environmental agreements	54		73
Fuel cost adjustment receivable	9		—
Environmental cleanup costs – Kingston ash spill	47		68
Total current regulatory assets	481		561
Non-current regulatory assets
Deferred pension costs and other post-retirement benefits costs	4,297		4,076
Unrealized losses on interest rate derivatives	957		808
Nuclear decommissioning costs	931		893
Environmental cleanup costs - Kingston ash spill	421		681
Non-nuclear decommissioning costs	645		571
Deferred nuclear generating units	1,255		1,438
Unrealized losses on commodity derivatives	72		139
Environmental agreements	108		189
Other non-current regulatory assets	308		336
Total non-current regulatory assets	8,994		9,131
Total regulatory assets	$	9,475	$	9,692
Current regulatory liabilities
Fuel cost adjustment tax equivalents	$	182	$	176
Fuel cost adjustment liability	—		29
Unrealized gains on commodity derivatives	2		7
Total current regulatory liabilities	184		212
Non-current regulatory liabilities
Unrealized gains on commodity derivatives	—		1
Total non-current regulatory liabilities	—		1
Total regulatory liabilities	$	184	$	213

Unrealized Gains (Losses) on Commodity Derivatives.  Unrealized gains (losses) on coal purchase contracts, included as part of unrealized losses on commodity derivatives, relate to the mark-to-market ("MtM") valuation of coal purchase contracts that contain options to purchase additional or lesser quantities.  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 2018.  Unrealized gains and losses on contracts with a maturity of less than one year are included as a current regulatory asset or liability on TVA's consolidated balance sheets.  See Note 15.

Deferred gains and losses relating to TVA’s Financial Trading Program ("FTP") represent net unrealized gains and losses on swaps, futures, options, and combinations of these instruments and are also included as part of unrealized losses on commodity derivatives.  The program is used to reduce TVA’s economic risk exposure associated with purchases and sales of commodities used in electricity generation, purchases, and sales.  TVA defers all FTP MtM unrealized gains or losses as regulatory liabilities or assets, respectively, and records realized gains or losses in fuel and purchased power expense to match the delivery period of the underlying commodity product.  Net unrealized losses at September 30, 2014, and September 30, 2013, were approximately $103 million and $166 million, respectively.  This accounting treatment reflects TVA’s ability and intent to recover the cost of these commodity contracts in future periods through the fuel cost adjustment.  The current regulatory asset/liability for net unrealized gains and losses, included as part of the commodity derivatives, represents deferred gains and losses from contracts with a maturity of less than one year.

Deferred Nuclear Generating Units and Construction Costs.  In July 2005, the TVA Board approved the amortization, and inclusion into rates, of TVA’s $3.9 billion investment in the two deferred nuclear generating units at Bellefonte over a 10-year

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recovery period beginning in 2006.  In August 2011, the TVA Board approved the completion of Bellefonte Unit 1. Approximately $619 million of the remaining balance in the deferred nuclear generating units regulatory asset at that date did not continue to be amortized into rates, but was to be included in the Bellefonte plant asset balance at completion. This amount had been segregated into a separate non-current regulatory asset account titled Construction costs. TVA is evaluating the completion of Bellefonte Unit 1. In the interim, work at the site has been slowed to better allocate resources on nearer-term priorities as both budget and staffing levels for the project have been reduced in the 2014 budget. TVA believes that the resulting budgeting and staffing levels should be sufficient to preserve Bellefonte for potential future development. TVA plans to utilize its integrated resource planning process to help determine how Bellefonte best supports TVA's overall efforts to continue to meet customer demand with low-cost, reliable power. In November 2013, in accordance with the regulated operations property, plant and equipment accounting guidance, the TVA Board approved the treatment of all amounts currently included in Construction in progress related to Bellefonte as a regulatory asset. Additionally, the TVA Board approved combining (1) the amounts related to Bellefonte previously included in Construction in progress, (2) the $619 million in Regulatory asset-Construction costs, and (3) the remaining amounts included in Regulatory asset-Deferred nuclear generating units into a single regulatory asset titled Deferred nuclear generating units totaling $1.5 billion at September 30, 2014. Such amounts have been classified as a Regulatory asset in the September 30, 2014 Consolidated Balance Sheet. The TVA Board approved the recovery of this asset in future rates at an amount of $237 million per year until fully recovered. The amount to be amortized over the next year is included as a current regulatory asset on TVA's consolidated balance sheets.

Environmental Agreements.  In conjunction with the Environmental Agreements (see Note 21 — Legal Proceedings — 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 2014, $138 million has been paid with respect to energy efficiency projects, $50 million has been paid to Alabama, Kentucky, North Carolina, and Tennessee, and $10 million has been paid with respect to civil penalties. The remaining amounts will be charged to expense and recovered in rates over future periods as payments are made.

Environmental Cleanup Costs – Kingston Ash Spill.  In August 2009, TVA began using 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 October 1, 2009. At September 30, 2009, TVA’s remediation cost estimate of $933 million was deferred as a regulatory asset. During 2010, the estimate was revised and increased by $192 million to a total estimate of $1.1 billion. The additional amount will be amortized over the remaining term. As of September 30, 2014, TVA had received insurance proceeds of $267 million, related to insurance claim settlements. The insurance proceeds are being recorded as reductions to the regulatory asset and will reduce 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. See Note 10.

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 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 are recovered or refunded in fuel rates.

Deferred Pension Costsand Other Post-retirement Benefit Costs.  TVA measures its benefit obligations related to pension and other post-retirement benefit ("OPEB") costs at each year-end balance sheet date.  TVA recognizes the funded status of the plans on TVA's consolidated balance sheets which in an unregulated environment would result in a corresponding offset to 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 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 in allowable costs for ratemaking purposes.

TVA has classified all amounts related to unrecognized prior service costs, net actuarial gains or losses, and the funded status as regulatory assets as such amounts are probable of collection in future rates. In 2015, TVA will begin including its cash contributions to the pension plan in the rate-making formula; accordingly, beginning October 1, 2014, TVA will recognize pension costs as regulatory assets to the extent that the amount calculated under GAAP as pension expense differs from the amount TVA contributes to the pension plan.

These regulatory assets are classified as long-term, which is consistent with the pension and post-retirement liabilities, and 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, as calculated by the

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actuaries. Ultimately this regulatory asset will be recognized in the consolidated statements of operations in the form of pension expense as the actuarial liability is eliminated in future periods. These costs are included in other non-current regulatory assets. See Note 20 — Obligations and Funded Status.

Unrealized Losses on Interest Rate Derivatives.  TVA uses regulatory accounting treatment to defer the MtM unrealized gains and losses on certain interest rate derivative contracts to reflect that the gain or loss is included in the ratemaking formula when these contracts actually settle.  The unrealized losses on these interest rate derivatives are recorded on TVA’s consolidated balance sheets as non-current regulatory assets and the related realized gains or losses, if any, are recorded in TVA’s consolidated statements of operations.

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 Nuclear Decommissioning Trust ("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— 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.

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 Asset Retirement Trust ("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 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.  There is not a specified recovery period; therefore, the regulatory asset is classified as long-term, consistent with the ART investments and ARO liability.

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

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.

Nuclear Training Costs.  As a result of refurbishing and restarting Browns Ferry Unit 1 in 2007 and the construction and startup of Watts Bar Nuclear Plant ("Watts Bar") Unit 2, nuclear training costs associated with these units have been deferred as a regulatory asset and will be amortized over a cost recovery period equivalent to the expected useful life of the operating nuclear units.

Retirement Removal Costs.  Retirement removal costs that are not legally required are capitalized into fixed assets to be depreciated consistent with the lives in the depreciation study. See Note 1 — Property, Plant, and Equipment, andDepreciation — Depreciation. The TVA Board has consistently set rates to cover the depreciation of these assets; therefore, these assets are probable of future recovery.

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, the percent of the calculation that relates to a future asset or liability for tax equivalent payments is recorded as a current regulatory asset or liability and paid in the following year.  

9.  Variable Interest Entities

A VIE is an entity that either (1) has insufficient equity to permit the entity to finance its activities without additional subordinated financial support or (2) has equity investors who lack the characteristics of owning a controlling financial interest. The analysis to determine whether an entity is a VIE considers factors such as contracts with an entity, credit support for an entity, the adequacy of the equity investment of an entity, the extent of an entity's activities that either involve or are conducted on behalf of an investor with disproportionate voting rights, and the relationship of voting power to the amount of equity invested in an entity. A VIE is consolidated by its primary beneficiary. The primary beneficiary has both (i) the power to direct the activities that most significantly impact the entity's economic performance and (ii) the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. The determination of the primary beneficiary requires continual reassessment.

When TVA determines that it has a variable interest in a variable interest entity, 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

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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.

Southaven

On August 9, 2013, TVA entered into a 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 Seven States Southaven, LLC ("SSSL"). SHLLC is a special single-purpose entity, also formed in June 2013, established to acquire and hold the membership interests of 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 scheduled amortizing, semi-annual payments due each August 15 and February 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. The sale of the SCCG notes, the membership interests in SCCG, and the SHLLC notes all closed on August 9, 2013. 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 scheduled pre-determined payments to be made to Seven States Southaven, LLC on each lease payment date by SHLLC as agreed in SHLLC’s formation documents (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.

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.

John Sevier

On January 17, 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 millionsecured 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 is allocated. 

The membership interests held by Holdco in JSCCG were purchased with proceeds from the issuance of $100 millionof secured notes (the “Holdco notes") and are subject to mandatory redemption pursuant to scheduled amortizing, semi-annual payments due each January 15 and July 15, with a final payment due on January 15, 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 on January 17, 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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The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG as of September 30, 2014 and 2013, as reflected in the Consolidated Balance Sheets, are as follows:

Summary of Impact of VIEs on Consolidated Balance Sheets At September 30
	2014		2013
Current liabilities of VIE
Accrued interest of VIE	$	12	$	12
Current portion of membership interests of VIE subject to mandatory redemption	2		2
Current maturities of long-term debt of VIE	32		30
Total current liabilities of VIE	46		44
Other liabilities of VIE
Membership interests of VIE subject to mandatory redemption	37		38
Long-term debt of VIE, net
Long-term debt of VIE	1,279		1,311
Total liabilities of VIE	$	1,362	$	1,393

Interest expense of $64 million, $50 million and $34 million related to debt of variable interest entities 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, 2014, 2013, and 2012, respectively.

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

10.  Kingston Fossil Plant Ash Spill

The Event

In December 2008, one of the dredge cells at Kingston failed, and approximately five million cubic yards of water and coal fly ash flowed out of the cell. TVA is continuing cleanup and recovery efforts in conjunction with federal and state agencies.  TVA completed the removal of time-critical ash from the river during the third quarter of 2010, and removal of the remaining ash is considered to be non-time-critical.  In November 2012, the EPA and the Tennessee Department of Environment and Conservation ("TDEC") approved a plan to allow the Emory River's natural processes to remediate the remaining ash in the river, and to conduct a long-term monitoring program. TVA estimates that the physical cleanup work will be completed in the spring of 2015.  A final assessment, issuance of a completion report, and approval by the State of Tennessee and the EPA are expected to occur by the third quarter of 2015.  

Claims and Litigation

See Note 21 — Legal Proceedings — Legal Proceedings Related to the Kingston Ash Spill and — Civil Penalty and Natural Resource Damages for the Kingston Ash Spill.

Financial Impact

TVA recorded an estimate of $1.1 billion for the cost of cleanup related to this event.  In August 2009, TVA began using regulatory accounting treatment to defer all actual costs already incurred and expected future costs related to the ash spill.  The cost is being charged to expense as it is collected in rates over 15 years, beginning October 1, 2009.  

Amounts spent since the event through September 30, 2014, totaled $1.1 billion.  The remaining estimated liability at September 30, 2014, was $21 million and is included in Current liabilities.

TVA has not included the following categories of costs in the above estimate since it has been determined that these costs are currently either not probable or not reasonably estimable: penalties (other than the penalties set out in a June 2010 TDEC order), regulatory directives, natural resources damages (other than payments required under a memorandum of agreement with TDEC and the U.S. Fish and Wildlife Service establishing a process and a method for resolving the natural resource damages claim), future lawsuits, future claims, long-term environmental impact costs, final long-term disposition of the ash processing area, and costs associated with new laws and regulations.  There are certain other costs that will be incurred that have not been included in the estimate as they are appropriately accounted for in other areas of the consolidated financial statements.  Associated capital asset purchases are recorded in property, plant, and equipment.  Ash handling and disposition costs from current plant operations are recorded in operating expenses.  A portion of the dredge cell closure costs are also excluded from the estimate, as they are included in the non-nuclear ARO liability.

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Insurance

TVA had property and excess liability insurance programs in place at the time of the Kingston ash spill.  TVA pursued claims under both the property and excess liability programs and has settled all of its property insurance claims and some of its excess liability insurance claims.  In April 2012, TVA initiated arbitration proceedings against the remaining excess liability insurance companies in accordance with the policies’ dispute resolution provisions. TVA is seeking recovery of certain costs incurred in the cleanup project, including the costs of removing ash from property or waters owned by the State of Tennessee, and related expenses. TVA has received insurance proceeds of $267 million, of which $175 million were received during the year ended September 30, 2014. The insurance proceeds are being recorded as reductions to the regulatory asset and will reduce costs collected in future rates.

11.  Other Long-Term Liabilities

Other long-term liabilities consist primarily of liabilities related to certain derivative agreements as well as liabilities under agreements related to compliance with certain environmental regulations (see Note 21 — Legal Proceedings — Environmental Agreements). The table below summarizes the types and amounts of Other long-term liabilities:

Other Long-Term Liabilities At September 30
	2014		2013
Interest rate swap liabilities	$	1,348	$	1,199
Environmental Agreements liability	108		190
EnergyRight® financing obligation	152		149
Membership interests of VIE subject to mandatory redemption	37		38
Commodity contract derivative liabilities	17		35
Commodity swap derivative liabilities	14		36
Currency swap liabilities	15		15
Other	271		199
Total other long-term liabilities	$	1,962	$	1,861

EnergyRight^® Purchase Obligation. TVA purchases certain loans receivable from its LPCs in association with the EnergyRight^® Solutions program. 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. Given this continuing involvement, TVA accounts for the transfer of the loans receivable as secured borrowings. 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, 2014 and September 30, 2013, the carrying amount of the financing obligation reported in Accounts payable and accrued liabilities was approximately $38 million and $37 million, respectively. See Note 7 for information regarding the associated loans receivable.

Membership Interests of VIE Subject to Mandatory Redemption. On August 9, 2013, SCCG issued 100 percent of its membership interests to SHLLC for a total of $40 million. The membership interests in SCCG are mandatorily redeemable pursuant to a schedule of payments that indicates the amount of each payment and the corresponding dates on which each payment is due. The schedule requires SCCG to make semi-annual payments to SHLLC sufficient to provide returns on, as well as returns of, capital until the investment has been repaid in full, including a $4 million balloon payment as part of the final disbursement which is due on August 15, 2033. The return on capital includes the Seven States Return. These payments provide a return on investment to SHLLC of 7.0 percent, which is reflected as interest expense in the consolidated statements of operations. As of September 30, 2014 and September 30, 2013, the carrying amount of the Membership interests of VIE subject to mandatory redemption was $39 million and $40 million, respectively. As of September 30, 2014 and 2013, $2 million of this was current and included in Accounts payable and accrued liabilities.

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.

12.  Asset Retirement Obligations

During the year ended September 30, 2014, TVA's total ARO liability decreased $319 million.

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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. Prior to June 30, 2014, TVA based its decommissioning cost estimates on cost elements prescribed by the NRC to dismantle and decommission the radioactive portion of each site with the assumption that decommissioning would occur within the first seven years after plant shut down, which approximates the DECON method of decommissioning. The DECON method requires that radioactive contamination is 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. On June 30, 2014, TVA recorded a change in estimate based on site-specific decommissioning cost studies. Additionally, TVA determined it appropriate to reflect an increase in the probability that certain of its nuclear operating licenses will be extended and that there is a probability that it will be able to delay ultimate decommissioning activities under a SAFSTOR method of decommissioning. 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. As such, TVA ascribed probabilities to both the SAFSTOR and DECON methods of decommissioning in order to estimate its decommissioning obligation. Decommissioning cost studies will be updated for each of TVA’s nuclear units at least every five years.

Additionally, both the nuclear and non-nuclear liabilities were increased by periodic accretion. This was partially offset by coal ash area settlement projects that were conducted during the year ended September 30, 2014. The nuclear and non-nuclear accretion were deferred as regulatory assets, and $40 million of the related regulatory assets was amortized into expense as this amount was collected in rates.

Asset Retirement Obligation Activity
	Nuclear			Non-Nuclear			Total
Balance at September 30, 2012	$	2,208		$	1,081		$	3,289
Settlements (ash storage areas)	—			(37		)	(37		)
Change in estimate (ash storage areas)	66			—			66
Accretion (recorded to regulatory asset)	125			45			170
Balance at September 30, 2013	$	2,399		$	1,089		$	3,488
Settlements (ash storage areas)	—			(14		)	(14		)
Change in estimate as a result of nuclear site-specific studies	(472		)	—			(472		)
Change in estimate (ash storage areas)	—			(10		)	(10		)
Accretion (recorded to regulatory asset)	125			52			177
Balance at September 30, 2014	$	2,052		$	1,117		$	3,169		(1)

Note

(1) The current portion of ARO in the amount of $80 million is 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, 2014, 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 United States, and the United States 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 out of 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.

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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; however, such treatment is not free from doubt. 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 minimum payments into the U.S. Treasury required by the TVA Act in repayment of, and as a return on, the Power Program Appropriation Investment, investment in power assets, additional reductions of TVA’s capital obligations, and other lawful purposes related to TVA’s power program.

The TVA Act and the Basic Resolution each contain two bond tests: the rate testand 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, 2014, TVA was in compliance with the rate test. See Note 1 — 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, 2010, and must next meet the bondholder protection test for the five-year period ending September 30, 2015.

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 was paid to TVA in accordance with the terms of the Southaven head lease. See Note 9 — Southaven. 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 9 — John Sevier. 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, 2014 and 2013 totaled approximately $1.3 billion.

Short-Term Debt

The weighted average rates applicable to short-term debt outstanding at September 30, 2014, 2013, and 2012, were nominal, 0.04 percent, and 0.09 percent, respectively.  During 2014, 2013, and 2012, the maximum outstanding balances of TVA short-term borrowings held by the public were $2.4 billion, $3.4 billion, and $3.2 billion, respectively.  For these same years, the average amounts (and weighted average interest rates) of TVA short-term borrowings were approximately $1.7 billion (0.05 percent), $1.9 billion (0.08 percent), and $1.1 billion (0.08 percent), respectively.

Put and Call Options

Bond issues of $515 million held by the public are redeemable in whole or in part, at TVA’s option, on call dates ranging from the present to 2020 and at call prices of 100 percent of the principal amount.  Fifteen Bond issues totaling $375 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 are classified as long-term as of September 30, 2014 and 2013.

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 six times, from an initial rate of 6.75 percent to the current rate of 3.830 percent.  In connection with these resets, $251 million of the Bonds have been redeemed, so that $324 million of the Bonds were outstanding at September 30, 2014.  The coupon rate for the 1999 Series A PARRS, which mature in May 2029, has been reset five times, from an initial rate of 6.50 percent to the current rate of 3.955 percent.  In connection with these resets, $255 million of the Bonds have been redeemed, so that $270 million of the Bonds were outstanding at September 30, 2014.

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, which occur in the third quarter of TVA's fiscal year.  If the 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.  At September 30, 2014, TVA has not determined that it is probable that the reset rate will be less than than the current coupon rate on the PARRS on the calculation dates; therefore, the par amount outstanding for each series of PARRS was classified as long-term debt.

Debt Securities Activity

The table below summarizes the long-term debt securities activity for the period from October 1, 2012, to September 30, 2014.

Debt Securities Activity For the years ended September 30
	2014			2013
Issues
Variable interest entities	$	—		$	360
electronotes®	—			152
2012 Series B(1)	—			1,000
2013 Series A(2)	—			1,000
2014 Series A(3)	1,000			—
Discount on debt issues	(11		)	(30		)
Total	$	989		$	2,482
Redemptions/Maturities(4)
Variable interest entities	$	30		$	13
electronotes®	335			50
1998 Series C	—			1,359
1998 Series D	—			2
1999 Series A	—			1
2003 Series C	—			940
2009 Series A	4			4
2009 Series B	26			2
Total	$	395		$	2,371

Notes

(1) The 2012 Series B bonds were issued at 97.49 percent of par.

(2) The 2013 Series A bonds were issued at 99.52 percent of par.

(3) The 2014 Series A bonds were issued at 98.94 percent of par.

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

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Debt Outstanding

Total debt outstanding at September 30, 2014, and 2013, consisted of the following:

Short-Term Debt At September 30
CUSIP or Other Identifier	Maturity	Call/(Put) Date	Coupon Rate	2014		2013
Short-term debt, net of discounts				$	596	$	2,432
Current maturities of long-term debt of variable interest entities issued at par				32		30
Current maturities of power bonds issued at par
880591EE8	11/15/2014		2.250%	3		3
880591EF5	12/15/2014		3.770%	26		26
880591DY5	6/15/2015		4.375%	1,000		—
88059TEL1	11/15/2014		2.650%	3		3
Total current maturities of power bonds issued at par				1,032		32
Total current debt outstanding, net				$	1,660	$	2,494

Long-Term Debt(1) At September 30
CUSIP or Other Identifier	Maturity	Coupon Rate			Call Date	2014 Par		2013 Par		Stock Exchange Listings
electronotes®(2)	05/15/2020 - 02/15/2043	2.375 - 4.375%			2/15/2015 - 02/15/2018	$	387	$	723	None
880591DY5	6/15/2015	4.375%				—		1,000		New York, Luxembourg
880591EE8(3)	11/15/2015	2.250%				2		4		None
880591DS8	12/15/2016	4.875%				524		524		New York
880591EA6	7/18/2017	5.500%				1,000		1,000		New York, Luxembourg
880591CU4	12/15/2017	6.250%				650		650		New York
880591EC2	4/1/2018	4.500%				1,000		1,000		New York, Luxembourg
880591EQ1	10/15/2018	1.750%				1,000		1,000		New York
880591EL2	2/15/2021	3.875%				1,500		1,500		New York
880591DC3	6/7/2021	5.805%	(4	)		324		324		New York, Luxembourg
880591EN8	8/15/2022	1.875%				1,000		1,000		New York
880591ER9	9/15/2024	2.875%				1,000		—		New York
880591CJ9	11/1/2025	6.750%				1,350		1,350		New York, Hong Kong, Luxembourg, Singapore
880591300(5)	6/1/2028	3.830%				324		324		New York
880591409(5)	5/1/2029	3.955%				270		270		New York
880591DM1	5/1/2030	7.125%				1,000		1,000		New York, Luxembourg

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880591DP4	6/7/2032	6.587%	(4	)		406			405			New York, Luxembourg
880591DV1	7/15/2033	4.700%				472			472			New York, Luxembourg
880591EF5(3)	6/15/2034	3.770%				388			414			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%	(4	)		243			243			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
Subtotal						22,037			22,400
Unamortized discounts, premiums, and other						(89		)	(85		)
Total long-term outstanding power bonds, net						21,948			22,315
Long-term debt of variable interest entities						1,279			1,311
Total long-term debt, net						$	23,227		$	23,626

Notes

(1)  Includes net exchange losses from currency transactions of $44 million at September 30, 2014 and $43 million at September 30, 2013.

(2)  Includes one electronotes^® issue with partial maturities of principal for each required annual payment.

(3)  These Bonds include partial maturities of principal for each required annual payment.

(4)  The coupon rate represents TVA’s effective interest rate.

(5)  TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions.  See Put and Call Options.

Maturities Due in the Year Ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Long-term power bonds and long-term debt of variable interest entities including current maturities(1)	$	1,064	$	65	$	1,590	$	1,718	$	1,070	$	18,829	$	24,336
Short-term debt, net of discounts	596		—		—		—		—		—		596

Note

(1) Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 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 fiscal year 2015 with a maturity date of September 30, 2015. 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 plans to use the credit facility as 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 United States with maturities from date of issue of one year or less. There were no outstanding borrowings under the facility at September 30, 2014. The availability of this credit facility may be impacted by how the U.S. government addresses the situation of approaching its debt limit.

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TVA also has funding available in the form of three long-term revolving credit facilities totaling $2.5 billion. One $1.0 billion credit facility matures on June 25, 2017, another $1.0 billion credit facility matures on December 13, 2017, and the $500 million credit facility matures on April 5, 2018. 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 $2.5 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, 2014, and September 30, 2013, there were $1.0 billion and $0.8 billion, respectively, of letters of credit outstanding under the facilities, and there were no borrowings outstanding. See Note 15 — Other Derivative Instruments — Collateral.

Lease/Leasebacks

Prior to 2004, TVA received approximately $945 million in proceeds by entering into leaseback transactions for 24 new peaking combustion turbine units ("CTs"). TVA also received approximately $389 million in proceeds by entering into a leaseback transaction for qualified technological equipment and software ("QTE") in 2003. Due to TVA's continuing involvement in the operation and maintenance of the leased units and equipment and its control over the distribution of power produced by the combustion turbine facilities during the leaseback term, TVA accounted for the lease proceeds as financing obligations. At September 30, 2014, and September 30, 2013, the outstanding leaseback obligations related to CTs and QTE were $691 million and $761 million, respectively.

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 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 year-ended September 30, 2014, TVA reclassified $2 million of gains related to its cash flow hedges from AOCI to Interest expense. See Note 15.

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 7, Note 15 — Overview of Accounting Treatment, Note 16, and Note 20.

15.  Risk Management Activities and Derivative Transactions

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 risks.  To help manage certain of these risks, TVA has entered into various derivative transactions: commodity option contracts, forward contracts, swaps, swaptions, futures, and options on futures.  Other than certain derivative instruments in investment funds, it is TVA's policy to enter into these derivative transactions solely for hedging purposes and not for speculative purposes.

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 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	2014		2013
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	$	4	$	78

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Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2) Amount of Gain (Loss) Reclassified from OCI to Interest Expense For the years ended September 30
Derivatives in Cash Flow Hedging Relationship	2014		2013
Currency swaps	$	2	$	1

Note

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 $37 million of losses from AOCI to interest expense within the next twelve months to offset amounts anticipated to be recorded in interest expense related to exchange gain on the debt.

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment Amount of Gain (Loss) Recognized in Income on Derivatives(1) For the years ended September 30
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2014			2013
Interest rate swaps	To fix short-term debt variable rate to a fixed rate (interest rate risk)	MtM gains and losses are recorded as regulatory assets or liabilities until settlement, at which time the gains/losses are recognized in gain/loss on derivative contracts.(2)	$	—		$	—
Commodity contract derivatives	To protect against fluctuations in market prices of purchased coal or natural gas  (price risk)	MtM gains and losses are recorded as regulatory assets or liabilities. Realized gains and losses due to contract settlements are recognized in fuel expense as incurred.	(64		)	(11		)
Commodity derivatives under FTP	To protect against fluctuations in market prices of purchased commodities (price risk)	MtM 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.	(43		)	(126		)

Notes

(1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there was no related gain (loss) recognized in income for these unrealized gains (losses) for the years ended 2014 and 2013.

(2) Generally, TVA maintains a level of outstanding discount notes equal to or greater than the notional amount of the interest rate swaps. However, in September 2014 TVA issued long-term Bonds in anticipation of the maturity of other long-term debt, and used the proceeds to pay down discount notes, which caused the balance of discount notes outstanding at September 30, 2014, to fall below the notional amount of the interest rate swaps. There is no impact on the statements of operations due to the use of regulatory accounting for these items.

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Mark-to-Market Values of TVA Derivatives At September 30
	2014				2013
Derivatives that Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Currency swaps
£200 million Sterling	$	(15	)	Other long-term liabilities	$	(15	)	Other long-term liabilities
£250 million Sterling	56			Other long-term assets	51			Other long-term assets
£150 million Sterling	8			Other long-term assets	10			Other long-term assets
Derivatives that Do Not Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Interest rate swaps
$1.0 billion notional	(987		)	Other long-term liabilities	(886		)	Other long-term liabilities
$476 million notional	(349		)	Other long-term liabilities	(300		)	Other long-term liabilities
$42 million notional	(12		)	Other long-term liabilities	(13		)	Other long-term liabilities
Commodity contract derivatives	(96		)	Other current assets $1; Other long-term liabilities $(17); Accounts payable and accrued liabilities $(80)	(141		)	Other long-term assets $1; Other current assets $2; Other long-term liabilities $(35); Accounts payable and accrued liabilities $(109)
FTP
Derivatives under FTP(1)	(103		)	Other current assets $(69); Other long-term liabilities $(14); Accounts payable and accrued liabilities $(20)	(166		)	Other current assets $(97); Other long-term liabilities $(36); Accounts payable and accrued liabilities $(33)

Note

(1)   Fair values of certain derivatives under the FTP that were in net liability positions totaling $69 million and $100 million at September 30, 2014 and September 30, 2013, respectively, are recorded in TVA's margin cash accounts in Other current assets. These derivatives are transacted with futures commission merchants, and cash deposits have been posted to the margin cash accounts held with each futures commission merchant to offset the net liability positions in full.

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, 2014:

Currency Swaps Outstanding At September 30, 2014
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 transaction gain on the Bond liability is offset by a currency exchange loss on the swap contract.  Conversely, when the dollar weakens against the British pound sterling, the transaction loss on the Bond liability is offset by an exchange gain on the swap contract.  All such exchange gains or losses on the Bond liability are included in Long-term debt, net.  The offsetting exchange losses or gains on the swap contracts are recognized in Accumulated other comprehensive income (loss).  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.

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Derivatives Not Receiving Hedge Accounting Treatment

Interest Rate Derivatives.  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 the transactions settle. The values of these derivatives are included in Other long-term assets or 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 2014 and 2013, the changes in market value of the interest rate derivatives resulted in deferred unrealized gains (losses) of $(149) million and $524 million, respectively.  There were no realized gains or losses for the years ended 2014 and 2013.

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. At September 30, 2014, and September 30, 2013, TVA's coal contract derivatives had net market values of $(86) million and $(140) million, respectively, which TVA deferred as regulatory assets or liabilities on a gross basis.  At September 30, 2014, TVA's coal contract derivatives had terms of up to three years.

The total market value of natural gas derivative contracts was $(10) million at September 30, 2014, and $(1) million at September 30, 2013. At September 30, 2014, natural gas derivative contracts had terms of up to two years.

Commodity Contract Derivatives At September 30
	2014					2013
	Number ofContracts	Notional Amount	Fair Value (MtM)			Number of Contracts	Notional Amount	Fair Value (MtM)
Coal contract derivatives	24	31 million tons	$	(86	)	19	43 million tons	$	(140	)
Natural gas contract derivatives	46	62 million mmBtu	$	(10	)	13	39 million mmBtu	$	(1	)

Derivatives Under FTP. While TVA is currently evaluating the use of financial instruments for price hedging, certain natural gas futures and swaps remain as part of the suspended FTP.TVA has a FTP under which it may purchase and sell futures, swaps, options, and combinations of these instruments (as long as they are standard in the industry) to hedge TVA’s exposure to (1) the price of natural gas, fuel oil, electricity, coal, emission allowances, nuclear fuel, and other commodities included in TVA’s fuel cost adjustment calculation, (2) the price of construction materials, and (3) contracts for goods priced in or indexed to foreign currencies. The combined transaction limit for the fuel cost adjustment and construction material transactions is $130 million (based on one-day value at risk). In addition, the maximum hedge volume for the construction material transactions is 75 percent of the underlying net notional volume of the material that TVA anticipates using in approved TVA projects, and the market value of all outstanding hedging transactions involving construction materials is limited to $100 million at the execution of any new transaction. The portfolio value at risk limit for the foreign currency transactions is $5 million and is separate and distinct from the $130 million transaction limit discussed above. TVA's policy prohibits trading financial instruments under the FTP for speculative purposes.

At September 30, 2014 and 2013, the risks hedged under the FTP were the economic risks associated with the prices of natural gas, fuel oil, and crude oil. At September 30, 2014 and 2013, TVA had no outstanding coal contract derivatives under the FTP. There were no futures contracts or options contracts outstanding under the FTP at September 30, 2014, and swap contracts under the FTP had remaining terms of three years or less.

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Derivatives under Financial Trading Program At September 30
	2014				2013
	Notional Amount	Fair Value (MtM) (in millions)			Notional Amount	Fair Value (MtM) (in millions)
Natural gas (in mmBtu)
Futures contracts	—	$	—		—	$	—
Swap contracts	102,227,500	(103		)	152,922,500	(169		)
Option contracts	—	—			—	—
Natural gas financial positions	102,227,500	$	(103	)	152,922,500	$	(169	)
Fuel oil/crude oil (in barrels)
Futures contracts	—	$	—		—	$	—
Swap contracts	—	—			1,205,000	3
Option contracts	—	—			—	—
Fuel oil/crude oil financial positions	—	$	—		1,205,000	$	3

Note

Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the broker or other counterparty.  Notional amounts disclosed represent the net absolute value of contractual amounts.

TVA defers all FTP unrealized gains (losses) as regulatory liabilities (assets) and records realized gains or losses to match the delivery period of the derivative contract. In addition to the open commodity derivatives disclosed above, TVA had closed derivative contracts with market values of $(5) million at September 30, 2014, and $(8) million at September 30, 2013. TVA experienced the following unrealized and realized gains and losses related to the FTP at the dates and during the periods, as applicable, set forth in the tables below:

Financial Trading Program Unrealized Gains (Losses) At September 30
FTP unrealized gains (losses) deferred as regulatory liabilities (assets)	2014			2013
Natural gas	$	(103	)	$	(169	)
Fuel oil/crude oil	—			3
Coal	—			—

Financial Trading Program Realized Gains (Losses) For the years ended September 30
Decrease (increase) in fuel expense	2014			2013
Natural gas	$	(34	)	$	(78	)
Fuel oil/crude oil	2			4
Coal	—			(1		)

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Financial Trading Program Realized Gains (Losses) For the years ended September 30
Decrease (increase) in purchased power expense	2014			2013
Natural gas	$	(11	)	$	(51	)

Offsetting of Derivative Assets and Liabilities

The amounts of TVA's derivative instruments as reported in the Consolidated Balance Sheets as of September 30, 2014, and September 30, 2013, are shown in the table below.

	As of September 30, 2014
	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
Currency swaps	$	64		$	(64	)	$	—
Commodity derivatives under FTP	51			(51		)	—
Total derivatives subject to master netting or similar arrangement	115			(115		)	—
Total derivatives not subject to master netting or similar arrangement	1			—			1
Total	$	116		$	(115	)	$	1
Liabilities
Currency swap (3)	$	(15	)	$	—		$	(15	)
Interest rate swaps (3)	(1,348		)	—			(1,348		)
Commodity derivatives under FTP	(154		)	120			(34		)
Total derivatives subject to master netting or similar arrangement	(1,517		)	120			(1,397		)
Total derivatives not subject to master netting or similar arrangement	(97		)	—			(97		)
Total	$	(1,614	)	$	120		$	(1,494	)
	As of September 30, 2013
	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
Currency swaps	$	61		$	(33	)	$	28
Commodity derivatives under FTP	101			(98		)	3
Total derivatives subject to master netting or similar arrangement	162			(131		)	31
Total derivatives not subject to master netting or similar arrangement	3			—			3
Total	$	165		$	(131	)	$	34
Liabilities
Currency swap (3)	$	(15	)	$	—		$	(15	)
Interest rate swaps (3)	(1,199		)	—			(1,199		)
Commodity derivatives under FTP	(267		)	198			(69		)
Total derivatives subject to master netting or similar arrangement	(1,481		)	198			(1,283		)
Total derivatives not subject to master netting or similar arrangement	(144		)	—			(144		)
Total	$	(1,625	)	$	198		$	(1,427	)

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 which are not offset in the balance sheets.

(3) Letters of credit of approximately $1.0 billion and $800 million were posted as collateral at September 30, 2014 and September 30, 2013, 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.

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Other Derivative Instruments

Investment Fund Derivatives.  Investment funds consist primarily of funds held in the NDT, ART, SERP, and LTDCP.  All securities in the trusts are classified as trading.  See Note 16 — Investments Funds for a discussion of the trusts' objectives and the types of investments included in the various trusts.  These trusts may invest in derivative instruments which may include swaps, futures, options, forwards, and other instruments.  At September 30, 2014, and September 30, 2013, the fair value of derivative instruments in these trusts was not material to TVA's consolidated financial statements.

Collateral.  TVA's interest rate swaps, currency swaps, and commodity derivatives under the FTP 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, 2014, the aggregate fair value of all derivative instruments with credit-risk related contingent features that were in a liability position was $1.4 billion.  TVA's collateral obligations at September 30, 2014, under these arrangements, was $900 million, for which TVA had posted $1.0 billion in letters of credit.  These letters of credit reduce the available balance under the related credit facilities.  TVA's assessment of the risk of its nonperformance includes a reduction in its exposure under the contract as a result of this posted collateral.

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

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

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

Counterparty Credit Risk

Credit risk is the exposure to economic loss that would occur as a result of a counterparty's nonperformance of its contractual obligations.  Where exposed to counterparty credit 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 employs credit mitigation measures, such as collateral or prepayment arrangements and master purchase and sale agreements, to mitigate credit risk.

Credit of Customers.  The majority of TVA's counterparty credit risk is associated with trade accounts receivable from delivered power sales to LPCs, all located in the Tennessee Valley region.  To a lesser extent, TVA is exposed to credit risk from directly served industries and federal agencies, and 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 had concentrations of accounts receivable from three customers that represented 27 percent of total outstanding accounts receivable at September 30, 2014 and 2013.

Credit of Derivative Counterparties.  TVA has entered into derivative contracts for hedging purposes, and TVA's NDT fund and qualified defined benefit pension plan have entered into derivative contracts for investment purposes.  If a counterparty to one of TVA's hedging transactions defaults, TVA might incur substantial costs in connection with entering into a replacement hedging transaction.  If a counterparty to the derivative contracts into which the NDT fund and the pension plan have entered for investment purposes defaults, the value of the investment could decline significantly or perhaps become worthless.  TVA has concentrations of credit risk from the banking and coal industries because multiple companies in these industries serve as counterparties to TVA in various derivative transactions.  At September 30, 2014, all of TVA's currency swaps, interest rate swaps, and commodity derivatives under the FTP were with counterparties whose Moody's credit rating was Baa2 or higher.  At September 30, 2014, all of TVA's coal contract derivatives were with counterparties whose Moody's credit rating, or TVA's internal analysis when such information was unavailable, was Caa1 or higher. See Derivatives Not Receiving Hedge Accounting Treatment.

TVA currently utilizes two active futures commission merchants ("FCMs") to clear commodity contracts, including futures, options, and similar financial derivatives. These transactions are executed under the FTP by the FCMs on exchanges on behalf of TVA. TVA maintains margin cash accounts with the FCMs. See notes to the Mark-to-Market Values of TVA Derivatives table.

Credit of 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 money that it paid to the supplier under the contract and have to purchase replacement fuel or power on the spot market, perhaps at a significantly higher price than TVA was entitled to pay under the contract.  In addition, TVA might not be able to acquire replacement fuel or power in a timely manner and thus might be unable to satisfy its own obligations to deliver power.  To help ensure a reliable supply of coal, TVA had coal contracts with multiple suppliers at September 30, 2014.  The contracted supply of coal is sourced from multiple geographic regions of the United States and is to be delivered via various transportation methods (for example, barge, rail, and truck).  TVA purchases the majority of its natural gas requirements from a variety of suppliers under short-term contracts.

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TVA has a power purchase agreement that expires on March 31, 2032, with a supplier of electricity for 440megawatts ("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.

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 3 is the lowest and Level 1 is the highest) 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 LTDCP assets, all changes in fair value of these assets and liabilities have been reflected in regulatory assets, regulatory liabilities, or accumulated other comprehensive income (loss) on TVA's consolidated balance sheets, and consolidated statements of comprehensive income (loss). Except for gains and losses on SERP and LTDCP assets, there has been no impact to TVA's consolidated statements of operations or its consolidated statements of cash flows related to these fair value measurements.

Investments Funds

At September 30, 2014, Investment funds were composed of $2.0 billion of securities classified as trading and measured at fair value and less than $1 million of equity investments not required to be measured at fair value. Trading securities are held in the NDT, ART, SERP, and LTDCP. The NDT holds funds for the ultimate decommissioning of TVA's nuclear power plants. The ART holds funds for the costs related to the future closure and retirement of TVA's long-lived assets. TVA established a SERP for certain executives in critical positions to provide supplemental pension benefits tied to compensation that exceeds limits set by Internal Revenue Service ("IRS") rules applicable to the qualified defined benefit pension plan. The LTDCP is designed to provide long-term incentives to executives to encourage them to stay with TVA and to provide competitive levels of total compensation to such executives. The NDT and SERP are invested in securities generally designed to achieve a return in line with overall equity market performance, and the ART and LTDCP are invested in securities generally designed to achieve a return in line with overall debt and equity market performance.

The NDT, ART, SERP, and LTDCP are composed of multiple types of investments and are managed by external institutional managers. Most U.S. and international equities, Treasury Inflation-Protected Securities, real estate investment trust securities, 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.

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Private partnership 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.  Investments in private partnerships generally involve a three-to-four-year period where the investor contributes capital.  This is followed by a period of distribution, typically over several years.  The investment period is generally, at a minimum, ten years or longer.  The NDT had unfunded commitments related to private partnerships of $113 million at September 30, 2014.  These investments have no redemption or limited redemption options and may also impose restrictions on the NDT’s ability to liquidate its investments.  There are no readily available quoted exchange prices for these investments.  The fair value of the investments is based on TVA’s ownership percentage of the fair value of the underlying investments as provided by the investment managers.  These investments are typically valued on a quarterly basis.  TVA’s private partnership 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 Level 3 within the fair value hierarchy. 

Commingled funds represent investment funds comprising multiple individual financial instruments. The commingled funds held by the NDT, ART, SERP, and LTDCP 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 (Level 1) or measured using observable inputs for similar instruments (Level 2). 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 Level 1 or Level 2 valuations.

Realized and unrealized gains and losses on trading 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 liability or asset account in accordance with TVA's regulatory accounting policy. See Note 1 — Cost-Based Regulation. TVA recorded unrealized gains and losses related to its trading securities held as of the end of each period as follows:

	Unrealized Investment Gains (Losses) At September 30
	Financial Statement Presentation	2014		2013
SERP	Other income (expense)	$	1	$	2
LTDCP	Other income (expense)	—		—
NDT	Regulatory asset	35		48
ART	Regulatory asset	15		33

Currency and Interest Rate Derivatives

See Note 15 — 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 and interest rate swaps. These swaps are classified as Level 2 valuations and are valued based on income approaches using observable market inputs for similar instruments.

Commodity Contract Derivatives and Commodity Derivatives Under FTP

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.

Commodity Derivatives Under FTP. These contracts are valued based on market approaches which utilize Chicago Mercantile Exchange ("CME") quoted prices and other observable inputs. Futures and options contracts settled on the CME are classified as Level 1 valuations. Swap contracts are valued using a pricing model based on CME inputs and are subject to nonperformance risk outside of the exit price. These contracts are classified as Level 2 valuations.

See Note 15 — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and— Derivatives Under FTP for a discussion of the nature and purpose of coal contracts and derivatives under TVA's FTP.

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 for 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 company. TVA discounts each financial instrument using the historical default rate (as reported by Moody’s for CY 1983 to CY 2013) 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, 2014.

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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, 2014, and September 30, 2013. 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, 2014
Assets	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Investments
Equity securities	$	162	$	—	$	—	$	162
Debt securities
U.S. government corporations and agencies	46		39		—		85
Corporate debt securities	—		290		—		290
Residential mortgage-backed securities	—		14		—		14
Commercial mortgage-backed securities	—		7		—		7
Collateralized debt obligations	—		29		—		29
Private partnerships	—		—		214		214
Commingled funds(2)							—
Equity security commingled funds	40		903		—		943
Debt security commingled funds	61		176		—		237
Total investments	309		1,458		214		1,981
Currency swaps(1)	—		—		—		—
Commodity contract derivatives	—		—		1		1
Commodity derivatives under FTP(1)
Swap contracts	—		—		—		—
Total commodity derivatives under FTP	—		—		—		—
Total	$	309	$	1,458	$	215	$	1,982
Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Currency swaps(1)	$	—	$	15	$	—	$	15
Interest rate swaps	—		1,348		—		1,348
Commodity contract derivatives	—		—		97		97
Commodity derivatives under FTP(1)
Swap contracts	—		34		—		34
Total commodity derivatives under FTP	—		34		—		34
Total	$	—	$	1,397	$	97	$	1,494

Notes

(1)  Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the counterparty or FCM. Deposits are made to TVA's margin cash accounts held with each FCM to offset any net liability positions in full for derivatives that are transacted with FCMs. TVA records currency swaps net of cash collateral received from or paid to the counterparty. See Note 15 — Offsetting of Derivative Assets and Liabilities.

(2) Commingled funds represent investment funds comprising multiple individual financial instruments and are classified in the table based on their existing investment portfolio as of the measurement date.  Commingled funds primarily composed of one class of security are classified in that category.

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Fair Value Measurements At September 30, 2013
Assets	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Investments
Equity securities	$	151	$	—	$	—	$	151
Debt securities
U.S. government corporations and agencies	38		67		—		105
Corporate debt securities	—		255		—		255
Residential mortgage-backed securities	—		25		—		25
Commercial mortgage-backed securities	—		7		—		7
Collateralized debt obligations	—		10		—		10
Private partnerships	—		—		159		159
Commingled funds(2)							—
Equity security commingled funds	—		741		—		741
Debt security commingled funds	—		248		—		248
Total investments	189		1,353		159		1,701
Currency swaps(1)	—		28		—		28
Commodity contract derivatives	—		—		3		3
Commodity derivatives under FTP(1)
Swap contracts	—		3		—		3
Total commodity derivatives under FTP	—		3		—		3
Total	$	189	$	1,384	$	162	$	1,735
Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Currency swaps(1)	$	—	$	15	$	—	$	15
Interest rate swaps	—		1,199		—		1,199
Commodity contract derivatives	—		1		143		144
Commodity derivatives under FTP(1)
Swap contracts	—		69		—		69
Total commodity derivatives under FTP	—		69		—		69
Total	$	—	$	1,284	$	143	$	1,427

Notes

(1)  Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the counterparty or FCM. Deposits are made to TVA's margin cash accounts held with each FCM to offset any net liability positions in full for derivatives that are transacted with FCMs. TVA records currency swaps net of cash collateral received from or paid to the counterparty. See Note 15 — Offsetting of Derivative Assets and Liabilities.

(2) Commingled funds represent investment funds comprising multiple individual financial instruments and are classified in the table based on their existing investment portfolio as of the measurement date.  Commingled funds primarily composed of one class of security are classified in that category.

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TVA uses internal and external valuation specialists for the calculation of its 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 assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3):

Fair Value Measurements Using Significant Unobservable Inputs
	Private Partnerships			Commodity Contract Derivatives
Balance at October 1, 2012	$	53		$	(267	)
Purchases	101			—
Issuances	—			—
Sales	(4		)	—
Settlements	—			—
Net unrealized gains (losses) deferred as regulatory assets and liabilities	9			127
Balance at September 30, 2013	159			(140		)
Purchases	39			—
Issuances	—			—
Sales	(9		)	—
Settlements	—			33
Net unrealized gains (losses) deferred as regulatory assets and liabilities	25			11
Balance at September 30, 2014	$	214		$	(96	)

There were $57 million of realized losses related to the instruments measured at fair value using significant unobservable inputs during the year ended September 30, 2014. All unrealized gains and losses related to these instruments have been reflected as increases or decreases in regulatory assets and liabilities. See Note 8.

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 2014		Valuation Technique(s)	Unobservable Inputs	Range
Assets
Commodity contract derivatives	$	1	Discounted cash flow	Credit risk	2 - 5 %	(1)
			Pricing model	Coal supply and demand	1.0 - 1.1 billion tons/year
				Long-term market prices	$11.24 - $67.07/ton
Liabilities
Commodity contract derivatives	$	97	Pricing model	Coal supply and demand	1.0 - 1.1 billion tons/year
				Long-term market prices	$11.24 - $67.07/ton

Note

(1) Applies to two contracts.

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Quantitative Information about Level 3 Fair Value Measurements
	Fair Value at September 30 2013		Valuation Technique(s)	Unobservable Inputs	Range
Assets
Commodity contract derivatives	$	3	Discounted cash flow	Credit risk	21	%	(1)
			Pricing model	Coal supply and demand	0.9 - 1.0 billion tons/year
				Long-term market prices	$10.25 - $85.25/ton
Liabilities
Commodity contract derivatives	$	143	Pricing model	Coal supply and demand	0.9 - 1.0 billion tons/year
				Long-term market prices	$10.25 - $85.25/ton

Note

(1) Applies to only one contract.

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 market value of the financial instruments held at September 30, 2014, and September 30, 2013, 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, 2014, and September 30, 2013, were as follows:

Estimated Values of Financial Instruments Not Recorded at Fair Value At September 30
		2014				2013
	Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value
EnergyRight® receivables (including current portion)	Level 2	$	156	$	166	$	150	$	150
Loans and other long-term receivables, net (including current portion)	Level 2	$	92	$	81	$	73	$	67
EnergyRight® purchase obligation (including current portion)	Level 2	$	190	$	215	$	186	$	222
Unfunded loan commitments	Level 2	$	—	$	18	$	—	$	13
Membership interests of variable interest entity subject to mandatory redemption (including current portion)	Level 2	$	39	$	50	$	40	$	50
Long-term outstanding power bonds (including current maturities), net	Level 2	$	22,980	$	26,889	$	22,347	$	24,603
Long-term debt of variable interest entities (including current maturities)	Level 2	$	1,311	$	1,425	$	1,341	$	1,386

Due to the short-term maturity of Cash and cash equivalents, Restricted cash and investments, and Short-term debt, net (each considered a Level 1 valuation classification), the carrying amounts of these instruments 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.

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The fair value of long-term debt traded in the public market is determined by multiplying the par value of the debt by the indicative market price at the balance sheet date. The fair value of other long-term debt and membership interests of variable interest entity 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. 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 an additional $1.0 billion of the Power Program Appropriation Investment has been repaid.  TVA paid $10 million for 2014 and $20 million for 2013 as a repayment of the Power Program Appropriation Investment. 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 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.

Summary of Proprietary Capital Activity At or for the years ended September 30
	2014						2013
Appropriation Investment	Power Program			Nonpower  Programs			Power Program			Nonpower  Programs
Balance at beginning of year	$	268		$	4,351		$	288		$	4,351
Return of power program appropriation investment	(10		)	—			(20		)	—
Balance at end of year	258			4,351			268			4,351
Retained Earnings
Balance at beginning of year	4,767			(3,742		)	4,492			(3,731		)
Net income (expense) for year	477			(8		)	282			(11		)
Return on power program appropriation investment	(4		)	—			(7		)	—
Balance at end of year	5,240			(3,750		)	4,767			(3,742		)
Net proprietary capital at September 30	$	5,498		$	601		$	5,035		$	609

Payments to the U.S. Treasury

TVA paid the U.S. Treasury $4 million in 2014, $7 million in 2013, and $7 million in 2012 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 1.97 percent, 2.10 percent, and 2.33 percent for 2014, 2013, and 2012, respectively.

Accumulated Other Comprehensive Income (Loss)

The items included in Accumulated other comprehensive income (loss) consist of market valuation adjustments for certain derivative instruments.  See Note 15.

TVA records exchange rate gains and losses on debt in net income and marks its currency swap assets and liabilities to market through other comprehensive income.  TVA had unrealized gains of $4 million and $78 million in 2014 and 2013, respectively, on the mark-to-market of currency swaps. TVA then reclassifies an amount out of accumulated other comprehensive income into net income, offsetting the gain/loss from recording the exchange gain/loss on the debt.  The amounts reclassified from other comprehensive income into net income resulted in increases to net income of $2 million, $1 million, and $35 million in 2014, 2013, and 2012, respectively.  These reclassifications, coupled with the recording of the exchange gain/loss on the debt, did not have an impact on net income in 2014, 2013, and 2012.  Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $37 million of losses from accumulated other comprehensive

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income to interest expense within the next twelve months to offset amounts anticipated to be recorded in interest expense related to exchange gain on the debt.

18.  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
	2014		2013			2012
Interest income	$	23	$	23		$	21
External services	19		18			7
Gains (losses) on investments	6		4			5
Miscellaneous	1		(1		)	—
Total other income (expense), net	$	49	$	44		$	33

19. Supplemental Cash Flow Information

Interest paid was $1.3 billion, $1.3 billion, and $1.4 billion in 2014, 2013, and 2012, respectively. These amounts differ from interest expense due to the timing of payments and interest capitalized of $175 million in 2014, $168 million in 2013, and $171 million in 2012 as a part of major capital expenditures. 

Construction in progress and Nuclear fuel expenditures included in Accounts payable and accrued liabilities at September 30, 2014, 2013, and 2012 were $391 million, $270 million, and $204 million, respectively, and are excluded from the Statements of Consolidated Cash Flows for the years ended 2014, 2013, and 2012 as non-cash investing activities.  In November 2013, in accordance with the regulated operations property, plant and equipment accounting guidance, the TVA Board approved the treatment of all amounts currently included in Construction in progress related to Bellefonte as a regulatory asset. Bellefonte amounts included in Construction expenditures for 2013 and 2012 were $162 million and $212 million, respectively.

TVA had non-cash activity related to financing activities on the 2014, 2013, and 2012 Consolidated Statements of Cash Flows related to capital leases of $70 million, $20 million, and $6 million, respectively.

Cash flows from futures contracts, forward contracts, option contracts, and 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.

20.  Benefit Plans

TVA sponsors a qualified defined benefit pension plan that covers most of its full-time employees, a qualified defined contribution 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.

Overview of Plans and Benefits

Retirement Plans.  TVA sponsors a qualified defined benefit pension plan and a qualified defined contribution 401(k) plan for most of its full-time annual employees hired prior to July 1, 2014, that provides two benefit structures: the Original Benefit Structure and the Cash Balance Benefit Structure. Eligible employees initially hired on or after January 1, 1996, must participate in the Cash Balance Benefit Structure. On April 11, 2014, the Tennessee Valley Authority Retirement System ("TVARS") Board approved amendments to the qualified defined benefit plan effective June 30, 2014. These amendments closed the defined benefit plan to new employees and certain rehires hired on or after July 1, 2014. These employees will be eligible for a retirement benefit as participants in the Employer Automatic Benefit Structure and will be eligible for a defined contribution benefit in the 401(k) plan only. A summary of the benefits provided by each structure is as follows:

• Original Benefit Structure.  The pension benefit for a member participating in the Original Benefit Structure is based on the member’s creditable service, the member’s average monthly salary for the highest three consecutive years of eligible compensation, and a pension factor based on the member’s age and years of service, less a Social Security offset. In addition, TVA makes matching contributions of 25 cents on the dollar (up to 1.5 percent of eligible compensation) to the 401(k) plan for members participating in the Original Benefit Structure.

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• Cash Balance Benefit Structure.  The pension benefit for a member participating in the Cash Balance Benefit Structure is based on credits accumulated in the member’s account and the member’s age.  A member’s account receives pay credits equal to six percent of his or her eligible compensation.  The account also receives interest credits at a rate set at the beginning of each calendar year equal to the change in the Consumer Price Index for All Urban Consumers ("CPI-U") plus three percent, with the provision that the rate may not be less than six percent or more than ten percent.  The interest crediting rate was six percent for calendar years 2014 and 2013. In addition, TVA makes matching contributions of 75 cents on the dollar (up to 4.5 percent of eligible compensation) to the 401(k) plan for members participating in the Cash Balance Benefit Structure.

• Employer Automatic Benefit Structure. Members participating in the Employer Automatic Benefit Structure receive an automatic, non-elective contribution by TVA to the 401(k) plan equal to 4.5 percent of eligible compensation and matching contributions by TVA to the 401(k) plan of 75 cents on the dollar (up to 4.5 percent of eligible compensation).

There are two investment funds within the defined benefit pension plan: the Fixed Benefit Fund and the Variable Fund.  TVA's plan contributions are deposited in the Fixed Benefit Fund.  Eligible employees in the Original Benefit Structure and Cash Balance Benefit Structure are allowed to make voluntary contributions to either the Variable Fund, the Fixed Fund within the Fixed Benefit Fund, or both.  Employee contributions are limited to $10,000 per year per eligible employee. The pension plan pays interest at the lesser of six percent or the actuarial assumed rate of return less 0.5 percent to employees in the Fixed Fund.  Employee contributions in the Fixed Fund were credited an annual rate of interest of six percent during 2014 and 2013, resulting in credit amounts of $33 million and $36 million, respectively.  Employee contributions to the Variable Fund are invested in an S&P 500 Stock Index Fund. 

The defined benefit pension plan and the defined contribution 401(k) plan are administered by a separate legal entity, TVARS, which is governed by its own board of directors (the "TVARS Board").  Upon notification by the TVARS Board of the minimum required and recommended contributions, TVA determines the level of contribution to make to TVARS to fund the defined benefit pension plan for the upcoming fiscal year.

In 2009, changes were made to the cost of living adjustment ("COLA") provisions of the defined benefit pension plan. The eligibility for the COLA became age 60 for employees who retire on or after January 1, 2010. In addition, the COLA was subject to caps for calendar years 2010 to 2013. As a result, the COLA for eligible retirees for the four years beginning January 1, 2010 were as follows:

•For CY 2010, the COLA was zero.

•For CY 2011, the COLA was 1.15 percent.

•For CY 2012, the COLA was zero.

•For CY 2013, the COLA was 2.3 percent.

In CY 2014, the COLA benefit of CPI-U, capped at 5.0 percent, was restored and was 1.53 percent.

Members of both the Original Benefit Structure and the Cash Balance Benefit Structure can also become eligible for a supplemental pension benefit based on age and years of service at retirement, which is designed to help offset the cost of retiree medical insurance.

401(k) Plan Contributions. TVA made non-elective and matching contributions of approximately $35 million to the plan during 2014, $34 million during 2013, and $34 million during 2012.

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.  TVA has historically funded the annual calculated expense.

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.

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 FECA.  FECA provides compensation and medical benefits to federal employees for permanent and temporary disability due to employment-related injury or disease.

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Accounting Mechanisms

Regulatory Accounting.  TVA has classified all amounts related to unrecognized prior service costs, net actuarial gains or losses, and the funded status as regulatory assets as such amounts are probable of collection in future rates. In 2015, TVA began including its cash contributions to the pension plan in the rate-making formula; accordingly, on October 1, 2014, TVA began recognizing pension costs as regulatory assets to the extent that the amount calculated under GAAP as pension expense differs from the amount TVA contributes to the pension plan.

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 active employees.

Asset Method.  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.  Since the “market-related” value of assets recognizes investment gains and losses over a three-year period, the future value of assets will be impacted as previously deferred gains or losses are recognized.  The “market-related” value is used in calculating expected return on plan assets and net gain or loss for pension cost determination.

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Obligations and Funded Status

The changes in plan obligations, assets, and funded status for the years ended September 30, 2014 and 2013, were as follows:

Obligations and Funded Status For the years ended September 30
	Pension Benefits						Other Post-Retirement Benefits
	2014			2013			2014			2013
Change in benefit obligation
Benefit obligation at beginning of year	$	11,471		$	11,995		$	656		$	811
Service cost	130			154			18			24
Interest cost	558			468			32			31
Plan participants’ contributions	28			29			—			—
Collections(1)	—			—			93			79
Amendments	2			4			—			—
Actuarial loss (gain)	722			(549		)	(21		)	(163		)
Net transfers from variable fund/401(k) plan	13			4			—			—
Expenses paid	(6		)	(6		)	—			—
Benefits paid	(653		)	(628		)	(126		)	(126		)
Benefit obligation at end of year	12,265			11,471			652			656
Change in plan assets
Fair value of net plan assets at beginning of year	7,221			7,029			—			—
Actual return on plan assets	648			787			—			—
Plan participants’ contributions	28			29			—			—
Collections(1)	—			—			93			79
Net transfers from variable fund/401(k) plan	13			4			—			—
Employer contributions(2)	256			6			33			47
Expenses paid	(6		)	(6		)	—			—
Benefits paid	(653		)	(628		)	(126		)	(126		)
Fair value of net plan assets at end of year	7,507			7,221			—			—
Funded status	$	(4,758	)	$	(4,250	)	$	(652	)	$	(656	)

Notes

(1) Collections include retiree contributions as well as federal reinsurance payments and provider discounts and rebates.

(2) Other Post-Retirement Benefits Employer contributions are reduced by federal reinsurance payments and provider discounts and rebates.

The pension actuarial loss above for 2014 primarily reflects the impact of the decrease in the discount rate from 5.00 percent to 4.45 percent, which increased the liability by approximately $729 million. Additional losses were due to demographic experience from the impact of TVA’s organizational restructuring in 2014. This increased the projected benefit obligation by $36 million. These losses were partially offset by the $88 million gain from the change in the retirement rates assumptions based on a five-year experience study.

The pension actuarial gain above for 2013 primarily reflects the impact of the increase in the discount rate from 4.00 percent to 5.00 percent, which decreased the liability by approximately $1.4 billion.  The actuarial gain was partially offset by the impact of including certain retiree benefits in the pension obligation which were not considered in prior periods, which increased the 2013 liability by $705 million.

The $21 million other post-retirement actuarial gain for 2014 was primarily due to demographic experience related to updated per capita claims costs and retiree contributions, which decreased the liability by $64 million. The change in the retirement rates assumptions provided an additional gain of $16 million. These gains were partially offset by the decrease in the discount rate from 5.05 percent to 4.50 percent and the reduction in force impact, which increased the obligation by $43 million and $17 million, respectively.

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The other post-retirement actuarial gain for 2013 primarily reflects the impact of the increase in the discount rate from 4.00 percent to 5.05 percent, which decreased the liability by $93 million. Additional gains were due to demographic experience related to per capita costs, contributions, participation rates, and changes in plan provisions, which decreased the liability by $43 million. Changes in the adjustment of the impact of the excise tax assumption decreased the liability by $33 million. These decreases in the post-retirement liability were slightly offset by the change in the COLA and mortality assumptions.

Amounts related to these benefit plans recognized on TVA's consolidated balance sheets consist of regulatory assets that have not been recognized as components of net periodic benefit cost at September 30, 2014 and 2013, 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
	2014			2013			2014			2013
Regulatory assets	$	4,157		$	3,910		$	140		$	166
Accounts payable and accrued liabilities	(5		)	(5		)	(38		)	(39		)
Pension and post-retirement benefit obligations(1)	(4,753		)	(4,245		)	(614		)	(617		)

Note

(1) Table above excludes $472 million and $486 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, 2014 and 2013, respectively.

Unrecognized amounts included in regulatory assets yet to be recognized as components of accrued benefit cost at September 30 consisted of:

Post-retirement Benefit Costs Deferred as Regulatory Assets At September 30
	Pension Benefits						Other Post-Retirement Benefits
	2014			2013			2014			2013
Unrecognized prior service cost (credit)	$	(180	)	$	(203	)	$	(39	)	$	(45	)
Unrecognized net loss	4,337			4,113			179			211
Total regulatory assets	$	4,157		$	3,910		$	140		$	166

The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for the pension plan at September 30, 2014, and 2013, were as follows:

Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets At September 30
	2014		2013
Projected benefit obligation	$	12,265	$	11,471
Accumulated benefit obligation	12,039		11,216
Fair value of net plan assets	7,507		7,221

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The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the years ended September 30, 2014, and 2013, were as follows:

Components of Net Periodic Benefit Cost For the years ended September 30
	Pension Benefits									Other Post-Retirement Benefits
	2014			2013			2012			2014			2013			2012
Service cost	$	130		$	154		$	139		$	18		$	24		$	19
Interest cost	558			468			490			32			31			35
Expected return on plan assets	(435		)	(428		)	(437		)	—			—			—
Amortization of prior service credit	(21		)	(22		)	(23		)	(6		)	(6		)	(6		)
Recognized net actuarial loss	285			377			361			11			25			29
Total net periodic benefit cost recognized	$	517		$	549		$	530		$	55		$	74		$	77

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 2015 At September 30, 2014
	Pension Benefits			Other Post-Retirement Benefits			Total
Prior service cost (credit)	$	(21	)	$	(6	)	$	(27	)
Net actuarial loss	277			8			285

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 At September 30
	Pension Benefits				Other Post-Retirement Benefits
	2014		2013		2014		2013
Assumptions utilized to determine benefit obligations at September 30
Discount rate	4.45	%	5.00	%	4.50	%	5.05	%
Rate of compensation increase	5.70	%	5.72	%	N/A		N/A
Initial health care cost trend rate	N/A		N/A		7.50	%	8.00	%
Ultimate health care cost trend rate	N/A		N/A		5.00	%	5.00	%
Ultimate trend rate is reached in year beginning	N/A		N/A		2019		2019
Assumptions utilized to determine net periodic benefit cost for the years ended September 30
Discount rate	5.00	%	4.00	%	5.05	%	4.00	%
Expected return on plan assets	7.25	%	7.25	%	N/A		N/A
Rate of compensation increase	5.72	%	4.44	%	N/A		N/A
Initial health care cost trend rate	N/A		N/A		8.00	%	8.50	%
Ultimate health care cost trend rate	N/A		N/A		5.00	%	5.00	%
Ultimate trend rate is reached in year beginning	N/A		N/A		2019		2019

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

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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. Based on recent market trends, TVA decreased its discount rate used to determine the pension benefit obligation and other post-retirement benefit obligation. At September 30, 2014, the discount rates used to determine the pension and other post-retirement benefit obligations for 2014 were 4.45 percent and 4.50 percent, respectively. At September 30, 2013, the discount rates used to determine the pension and other post-retirement benefit obligations were 5.00 percent and 5.05 percent, respectively. The discount rate assumptions used to determine the obligations at year-end are used to determine the net periodic benefit costs for the following year.

Rate of Return.  The qualified defined benefit pension plan is the only plan that is funded with qualified plan

assets. In determining its 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 and asset class factors. 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 current asset allocation policy approved by the TVARS Board 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 change in the funded status of TVARS. Changes in the expected return rates are based on annual studies performed by third party professional investment consultants. Based upon the results from the 2014 annual study, TVA adjusted the assumption from 7.25 percent that was used to measure the 2014, 2013, and 2012 net periodic pension benefit cost, to a 7.00 percent expected rate of return that will be used to measure the 2015 net periodic benefit 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 2013 and determined that future compensation would likely increase at rates between 3.50 percent and 13.00 percent per year, depending upon the employee's age. Based upon the current active participants, the average assumed compensation increase used to determine benefit obligations for 2014 and 2013 was 5.70 percent and 5.72 percent, respectively. The average assumed compensation increase to determine net periodic pension benefit costs for 2014, 2013, and 2012 were 5.72 percent, 4.44 percent, and 4.43 percent, respectively.

Mortality.  Mortality assumptions are based on the results obtained from a recent actual company experience study performed, which included retirees as well as other plan participants. TVA obtained an updated study in 2013, which indicated an improvement in TVA's mortality experience. Accordingly, TVA adjusted the projection period for the RP-2000 Mortality Tables for males and females projected to 2022 using scale AA at September 30, 2013. Additional experience per the actuarial review in 2014 indicated that actual experience remains in line with the assumption adopted in 2013. Therefore, TVA maintained this assumption for 2014. At September 30, 2012, the projection period for the RP- 2000 Mortality Tables for males and females was projected to 2013 using scale AA.

Health Care Cost Trends. TVA reviews actual recent cost trends and projected future trends in establishing health care cost trend rates. The assumed health care trend rates used to determine post-retirement benefit obligations for 2014 and 2013 were 7.50 percent and 8.00 percent, respectively. The 2014 health care cost trend rate of 7.50 percent used to determine post-retirement benefit obligations is assumed to gradually decrease each successive year until it reaches a 5.00 percent annual increase in health care costs in the years beginning October 1, 2019, and beyond. The assumed health care cost trend rates used to determine the net periodic post-retirement cost were 8.00 percent for 2014, 8.50 percent for 2013, and 8.00 percent for 2012. TVA plans to use 7.50 percent in the determination of 2015 net periodic post-retirement cost. TVA had increased the rate from 2012 to 2013 based upon exhibited annual increases in costs per covered life due primarily to changes in inflation, utilization, and healthcare regulations. Costs in 2014 have decreased in line with the actuarial expectations as a result of plan changes and prescription drug coverage.

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 may receive a COLA on the base pension portion of the monthly pension benefit 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. The minimum COLA is one percent and the maximum is five percent. The COLA was temporarily reduced for a four-year period beginning January 1, 2010, for current retirees, and the eligibility for the COLA was changed to age 60 from attained age 55 for employees retiring on or after January 1, 2010. The COLA assumption was 2.50 percent from 2009 to 2012; however, in 2013, TVA adjusted the COLA assumption due to the Federal Reserve System’s long-term monetary policy and the market-based expectations that inflation will remain below two percent into 2015. TVA adjusted the COLA assumption at September 30, 2013, to 1.6 percent with an assumed gradual increase each successive year until it reaches 2.50 percent in 2020. At September 30, 2014, the COLA is assumed to increase to 2.0 percent with an assumed gradual increase each successive year until it reaches 2.50 percent in 2020.

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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, 2014
Actuarial Assumption	Change in Assumption		Impact on 2014 Pension Cost		Impact on 2014 Projected Benefit Obligation
Discount rate	(0.25	)	$	18	$	369
Rate of return on plan assets	(0.25	)	15		N/A

Each fluctuation above assumes that the other components of the calculation are held constant and excludes any impact for unamortized actuarial gains or losses.

The following chart reflects the sensitivity of post-retirement benefit cost to changes in the health care trend rate:

Sensitivity to Changes in Assumed Health Care Cost Trend Rates At September 30, 2014
	1% Increase		1% Decrease
Effect on total of service and interest cost components for the year	$	7	$	(7	)
Effect on end-of-year accumulated post-retirement benefit obligation	89		(93		)

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 qualified defined benefit pension plan (the "Plan"), which includes the Original Benefit Structure and the Cash Balance Benefit Structure, is the only plan that includes qualified plan assets. TVARS has a long-term investment plan which contains a dynamic de-risking strategy that allocates investments to assets that better match the liability, such as long duration fixed income securities, over time as funding status targets are met. The investment asset allocation policy approved by the TVARS Board has targets of 47 percent equity including U.S., non-U.S., private, and low volatility global public equity investments, 28 percent fixed income securities, 15 percent public real assets including Treasury Inflation-Protected Securities ("TIPS"), commodities, and Master Limited Partnerships ("MLPs"), and 10 percent private real assets. The qualified pension plan assets are invested across global public equity, private equity, cash, core fixed income, long-term core fixed income, investment grade credit, high yield fixed income, emerging markets fixed income, global TIPS, commodities, MLPs, and private real assets. The TVARS asset allocation policy includes permissible deviations from these target allocations. The TVARS Board can take action, as appropriate, to rebalance the system’s assets consistent with the asset allocation policy. At September 30, 2014 and 2013, the asset holdings of the system included the following:

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Asset Holdings of TVARS At September 30
			Plan Assets at September 30
Asset Category	Target Allocation		2014		2013
Global equity	32	%	43	%	48	%
Private equity	10	%	5	%	6	%
Low volatility global public equity	5	%	1	%	—	%
Cash	2	%	2	%	2	%
Core fixed income	5	%	5	%	5	%
Long-term core fixed income	5	%	5	%	4	%
Investment grade credit	6	%	6	%	6	%
International emerging markets fixed income	5	%	5	%	—	%
High yield fixed income	5	%	6	%	10	%
Global TIPS	5	%	5	%	7	%
Private real assets	10	%	7	%	7	%
Commodities	5	%	4	%	—	%
MLPs	5	%	6	%	5	%
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, 2014:

TVA Retirement System At September 30, 2014
	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	$	1,669	$	1,668	$	—	$	1
Preferred securities	37		5		32		—
Debt securities
Corporate debt securities	1,326		—		1,304		22
Residential mortgage-backed securities	204		—		201		3
Debt securities issued by U.S. Treasury and other U.S. government agencies	93		93		—		—
Debt securities issued by foreign governments	225		—		218		7
Asset-backed securities	176		—		147		29
Debt securities issued by state/local governments	30		—		29		1
Commercial mortgage-backed securities	23		—		20		3
Commingled Funds
Equity	1,106		—		1,106		—
Debt	661		—		661		—
Commodity	332		—		332		—
Blended	228		—		228		—
Institutional mutual funds	28		28		—		—
Cash equivalents and other short-term investments	464		—		464		—
Certificates of deposit	19		—		19		—
Private equity funds	481		—		—		481
Private real estate funds	435		—		334		101
Treasury bills, U.S. Government notes, and securities held as futures and other derivative collateral	35		10		25		—
Securities lending commingled funds	2		—		2		—
Derivatives
Purchased options	18		—		18		—
Foreign currency forward receivable	8		—		8		—
Total Assets	$	7,600	$	1,804	$	5,148	$	648
Liabilities
Derivatives
Futures	11		$	11	$	—	$	—
Foreign currency forward payable	8		—		8		—
Written option obligations	7		—		7		—
Total Liabilities	$	26	$	11	$	15	$	—

Notes

(1) Excludes approximately $65 million in net payables associated with security purchases and sales and various other payables.

(2) Excludes a $2 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

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The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2013:

TVA Retirement System At September 30, 2013
	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	$	1,689	$	1,686	$	—	$	3
Preferred securities	22		17		—		5
Debt securities
Corporate debt securities	1,352		—		1,334		18
Residential mortgage-backed securities	355		—		352		3
Debt securities issued by U.S. Treasury and other U.S. government agencies	113		113		—		—
Debt securities issued by foreign governments	31		—		30		1
Asset-backed securities	120		—		110		10
Debt securities issued by state/local governments	36		—		36		—
Commercial mortgage-backed securities	21		—		18		3
Commingled Funds
Equity	1,182		—		1,182		—
Debt	786		—		786		—
Blended	263		—		263		—
Institutional mutual funds	26		26		—		—
Cash equivalents and other short-term investments	395		1		394		—
Private equity funds	528		—		—		528
Private real estate funds	382		—		297		85
Treasury bills, U.S. Government notes, and securities held as futures and other derivative collateral	39		8		31		—
Securities lending commingled funds	3		—		3		—
Derivatives
Foreign currency forward receivable	6		—		6		—
Purchased options	6		—		6		—
Credit default swaps	4		—		4		—
Written option obligations	4		4		—		—
Total Assets	$	7,363	$	1,855	$	4,852	$	656
Liabilities
Derivatives
Foreign currency forward payable	$	6	$	—	$	6	$	—
Credit default swaps	1		—		1		—
Written option obligations	1		—		1		—
Total Liabilities	$	8	$	—	$	8	$	—

Notes

(1) Excludes approximately $131 million in net payables associated with security purchases and sales and various other payables.

(2) Excludes a $3 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

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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, 2012	$	633
Net realized/unrealized gains (losses)	45
Purchases, sales, issuances, and settlements (net)	(21		)
Transfers in and/or out of Level 3	(1		)
Balance at September 30, 2013	656
Net realized/unrealized gains (losses)	50
Purchases, sales, issuances, and settlements (net)	(53		)
Transfers in and/or out of Level 3	(5		)
Balance at September 30, 2014	$	648

The following descriptions of the valuation methods and assumptions used by the Plan to estimate the fair value of investments apply to investments held directly by the Plan. Third-party pricing vendors provide valuations for investments held by the Plan in most instances, except for commingled, private equity, and private real estate funds which are priced at net asset values established by the investment managers with possible adjustment by management to reflect estimated current fair value. In instances where pricing is determined to be based on unobservable inputs, or where liquidity restrictions exist in the case of funds valued at net asset value, a Level 3 classification has been assigned.

Equities and Preferred Securities. Investment securities, including common stock, mutual funds, and preferred securities 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. If there are no current day sales, the securities are valued at their last quoted bid price. Equities and preferred securities priced by an exchange in an active market are classified as Level 1. 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.

Corporate Debt Securities. Most 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 developed by sources considered by management to be reliable. 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).

Residential Mortgage-Backed Securities. Residential mortgage-backed securities consist of collateralized mortgage obligations ("CMOs") and U.S. pass-through security pools related to government-sponsored enterprises ("GSE"). 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 GSE 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.

U.S. Treasury and Agency Securities. 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). Agency securities are typically priced using evaluated pricing applications and models incorporating U.S. Treasury yield curves. Agency securities are classified as Level 2 because of the nature of their market-data-based pricing models.

Debt Securities Issued by Foreign Governments. These include foreign government bonds and foreign government inflation-linked securities. They are typically priced based on proprietary discounted cash flow models, incorporating option-

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adjusted spread features as appropriate. Most debt securities issued by foreign governments are classified as Level 2 because of the nature of their market-data-based pricing models.

Asset-Backed Securities. 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, most asset-backed securities are classified as Level 2.

Debt Securities Issued by State and Local Governments. Most debt securities issued by state and local governments are 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.

Commercial Mortgage-Backed Securities. Commercial mortgage-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, most commercial mortgage-backed securities are classified as Level 2.

Commingled Funds. The 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 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 (Level 2 inputs). These net asset values may be adjusted by management if it is determined that they do not reflect a current estimate of fair value.

The 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, the S&P 500 index, and the Morgan Stanley Capital International All Country World Index ex-U.S. 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 Plan is invested in actively managed debt commingled funds which 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. The objective is to achieve a positive relative total return through active credit selection.

The 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 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 Plan’s investments in equity, debt, blended, and commodity commingled funds can generally be redeemed at any time upon notification of the investment managers, with required notice periods varying from same-day to monthly.

Institutional Mutual Funds. Participation units of institutional mutual funds are stated at their quoted redemption values as reported by the investment managers based on their net asset values, which reflect the fair values of the underlying investments. These funds are traded at published net asset values in an active market (Level 1 inputs).

Cash Collateral Held Under Securities Lending Arrangements. Fair value has been determined to approximate the deposit account balances held in cash collateral pools (Level 2 inputs), as no discounts for credit quality or liquidity were determined to be applicable.

Cash Equivalents and Other Short-Term Investments and Certificates of Deposit. Cash equivalents and other short-term investments are highly liquid securities with a maturity 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.

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Private Equity Funds. Private equity limited partnerships are reported at net asset values provided by the fund managers. These net asset values may be adjusted by management if it is determined that they do not reflect a current estimate of fair value.

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; 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. 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, and as such are classified as Level 3. Partnerships generally continue 10 to 12 years after the inception of the fund. The partnerships are subject to three to fourone-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 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 Plan’s private real estate investments are estimated utilizing net asset values provided by the investment managers. These net asset values may be adjusted by management if it is determined that they do not reflect a current estimate of fair value. The methodologies utilized by the investment managers to calculate their net asset values are summarized as follows:

The 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 Plan is invested in a commingled fund that develops, renovates, and re-leases real estate properties to create value. Investments are predominantly in top tier real estate markets that offer deep liquidity. Property types include residential, office, industrial, hotel, retail, and land. Properties are diversified by geographic region within the U.S. domestic market. The Plan is invested in a second commingled fund that invests primarily in core, well-leased, operating real estate properties with a focus on income generation. Investments are diversified by property type with a focus on office, industrial, apartment, and retail. Properties are diversified within the U.S. with an overweight to major market and coastal regions.

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 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.

The fair value hierarchy level classifications for the Plan’s real estate investments are determined based on redemption terms. Investments which cannot be redeemed at the measurement date, but which can be redeemed at a future date, are evaluated based on the length of time until the investment will become redeemable in determining whether the investment should be reported in either Level 2 or Level 3 of the fair value hierarchy. The redemption provisions vary by fund.

Derivatives. The Plan invests in a variety of derivative instruments. The valuation methodologies for these instruments are as follows:

Options. The 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

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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.

Foreign currency forwards. The 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. Foreign currency forwards are disclosed on a net position basis.

Futures. The Plan enters into futures. The futures contracts are listed on either a national or foreign securities exchange and 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.

Swaps. The 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. 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. 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 Plan's swaps are generally classified as Level 2 based on the observable nature of their pricing inputs.

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 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.

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, 2014
	Pension Benefits		Other Post-Retirement Benefits
2015	$	712	$	39
2016	715		40
2017	720		41
2018	724		41
2019	731		41
2020 - 2024	3,759		186

Contributions.  In 2009, TVA made a contribution to TVARS of $1.0 billion for 2010 and as an advance on contributions for 2011 through 2013. In 2011, TVA made an additional discretionary contribution of $270 million to TVARS. In 2013 and 2012, the qualified defined pension plan's assets exceeded market return expectations and no discretionary contributions were made. The minimum contribution for 2014 was $198 million; however, TVA made a $250 million contribution to TVARS. The 2015 minimum contribution is $215 million; however, TVA expects to contribute $275 million to TVARS in 2015. In 2014, TVA made contributions of $6 million to the SERP and $47 million to the other post-retirement benefit plans. TVA expects to contribute $5 million to the SERP and $39 million to the other post-retirement benefit plans in 2015.

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 2.52 percent discount rate resulted in the recognition of approximately $34 million in expenses in 2014 and an unpaid benefit obligation of about $520 million at September 30, 2014. The 2014 current portion of the obligation is $48 million and is recorded in Accounts payable and accrued liabilities. The 2014 long-term portion of $472 million is recorded in Post-retirement and post-employment benefit obligations. The amounts in the current portion of the obligation represent the total unpaid losses and administrative fees for each year that are due one month following TVA’s fiscal year end.

The use of a 2.64 percent discount rate resulted in the recognition of approximately $(8) million in expenses in 2013 and an unpaid benefit obligation of about $535 million at September 30, 2013. The 2013 current portion of the obligation is $49

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million and is recorded in Accounts payable and accrued liabilities. The 2013 long-term portion of $486 million is recorded in Post-retirement and post-employment benefit obligations. TVA utilized discount rates of 1.65 percent in 2012 resulting in expense of $52 million and a $597 million obligation.

The decrease in the unpaid benefit obligation from 2014 to 2013 is due primarily to the demographic experience gains from decreases in loss experiences and fewer claimants. The decrease in the unpaid benefit obligation and expense from 2012 to 2013 is due primarily to the increase in the discount rate from 1.65 percent in 2012 to 2.64 percent in 2013 resulting in a decrease of $45 million.  Decreases in loss experiences and other changes in demographic experiences also decreased the unpaid benefit obligation and expense to a lesser degree.

21. Commitments and Contingencies

Commitments

At September 30, 2014, the amounts of contractual cash commitments maturing in each of the next five years and beyond are shown below:

Commitments and Contingencies Payments due in the years ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Debt(1)	$	1,628	$	32	$	1,555	$	1,682	$	1,032	$	17,692	$	23,621
Debt of VIEs	32		33		35		36		38		1,137		1,311
Membership interests of variable interest entity subject to mandatory redemption	2		2		2		2		2		29		39
Lease obligations
Capital	13		13		13		13		12		167		231
Non-cancelable operating	38		36		34		27		25		63		223
Purchase obligations
Power	220		222		232		235		239		3,364		4,512
Fuel	1,335		862		477		552		492		1,579		5,297
Other	304		215		202		199		192		1,640		2,752
Unfunded loan commitments	13		—		—		—		—		—		13
Payments on other financings	104		104		104		104		96		305		817
Total	$	3,689	$	1,519	$	2,654	$	2,850	$	2,128	$	25,976	$	38,816

Note

(1) Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million.

In addition to the cash requirements, above, TVA has contractual obligations in the form of revenue discounts related to energy prepayments.  See Note 1 — Energy Prepayment Obligations and Discounts on Sales.

Energy Prepayment Obligations Payments due in the years ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Energy Prepayment Obligations	$	100	$	100	$	100	$	100	$	10	$	—	$	410

Debt. At September 30, 2014, TVA had outstanding discount notes of $596 million and long-term debt (including current maturities) at varying maturities and interest rates of $23.0 billion for total outstanding indebtedness of $23.6 billion. See Note 13.

Debt of VIEs. At September 30, 2014, TVA had outstanding long-term debt (including current maturities) attributable to its three VIEs of which it is the primary beneficiary of $1.3 billion. See Note 9.

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Membership Interests of VIE Subject to Mandatory Redemption. At September 30, 2014, TVA had outstanding membership interests subject to mandatory redemption (including current portion) of $39 million issued by one of its VIEs of which it is the primary beneficiary. See Note 9.

Leases.  TVA leases certain property, plant, and equipment under agreements with terms ranging from one to 80 years.  Of the total obligations for TVA’s capital leases, $124 million represents the cost of financing.  TVA’s rental expense for operating leases was $75 million in 2014, $71 million in 2013, and $67 million in 2012.

Power Purchase Obligations.  TVA has contracted with various independent power producers and LPCs for additional capability to be made available to TVA. Several of these agreements have contractual minimum payments.  In total, these agreements provide 1,621 MW of summer net capability.  The remaining terms of the agreements range up to 18 years.  TVA incurred $293 million, $322 million, and $447 million of expense under power purchase agreements during 2014, 2013, and 2012, respectively.  Certain power purchase obligations are accounted for as capital leases. Costs under TVA’s power purchase agreements not 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, 2014, there was a combined qualifying capacity of 890 MW from six different suppliers, from which TVA purchased power under this law.  TVA’s obligations to purchase power from these qualifying facilities are not included in the Commitments and Contingencies table.

TVA, along with others, contracted with the Southeastern Power Administration ("SEPA") to obtain power and energy from eight U.S. Army Corps of Engineers hydroelectric facilities on the Cumberland River system.  The agreement with SEPA can be terminated upon three years’ notice, but this notice of termination may not become effective prior to June 30, 2017.  The contract requires SEPA to provide TVA an annual minimum of 1,500 hours of energy for each megawatt of TVA’s 405 MW allocation, and all surplus energy from the Cumberland River system.  TVA’s obligations under its contract with SEPA are not included in the Commitments and Contingencies table.

Fuel Purchase Obligations.  TVA has approximately $1.6 billion in long-term fuel purchase commitments ranging in terms of up to 6 years primarily for the purchase and transportation of coal.  TVA also has approximately $3.7 billion of long-term commitments ranging in terms of up to 16 years for the purchase of enriched uranium and fabrication of nuclear fuel assemblies.

Other Obligations.  Other obligations of $2.8 billion consist of contracts at September 30, 2014, for goods and services primarily related to capital projects as well as other major recurring operating costs.

Contingencies

Nuclear Insurance.  The Price-Anderson Act provides a layered framework of protection to compensate for losses arising from a nuclear event in the United States.  For the first layer, all of the NRC nuclear plant licensees, including TVA, purchase $375 million of nuclear liability insurance from American Nuclear Insurers for each plant with an operating license.  Funds for the second layer, the Secondary Financial Program, would come from an assessment of up to $127 million from the licensees of each of the 104 NRC licensed reactors in the United States.  The assessment for any nuclear accident would be limited to $19 million per year per unit.  American Nuclear Insurers, under a contract with the NRC, administers the Secondary Financial Program.  With its six licensed units, TVA could be required to pay a maximum of $764 million per nuclear incident, but it would have to pay no more than $114 million per incident in any one year.  When the contributions of the nuclear plant licensees are added to the insurance proceeds of $375 million, over $13.0 billion, including a five percent surcharge for legal expenses, would be available.  Under the Price-Anderson Act, if the first two layers are exhausted, the U.S. Congress is required to take action to provide additional funds to cover the additional losses.

TVA carries property, decommissioning, and decontamination insurance of $5.1 billion for its licensed nuclear plants, with up to $2.1 billion available for a loss at any one site, to cover the cost of stabilizing or shutting down a reactor after an accident.  Some of this insurance, which is purchased from Nuclear Electric Insurance Limited ("NEIL"), may require the payment of retrospective premiums up to a maximum of approximately $120 million.

TVA purchases accidental outage (business interruption) insurance for TVA’s nuclear sites from NEIL.  In the event that an accident covered by this policy takes a nuclear unit offline or keeps a nuclear unit offline, NEIL will pay TVA, after a waiting period, an indemnity (a set dollar amount per week) up to a maximum indemnity of $490 million per unit.  This insurance policy may require the payment of retrospective premiums up to a maximum of approximately $35 million.

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

Nuclear.  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,

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2014, the present value of the estimated future decommissioning cost of $2.1 billion 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 the difference in the discount rates used to calculate the present value of decommissioning costs.

TVA maintains a NDT to provide funding for the ultimate decommissioning of its nuclear power plants.  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 will be available to support decommissioning.  TVA’s nuclear power units are currently authorized to operate until 2020-2036, 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 — Nuclear Decommissioning Costs and Note 12.

Non-Nuclear Decommissioning.  The present value of the estimated future non-nuclear decommissioning cost ARO was $1.1 billion at September 30, 2014.  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 power assets.  Estimates involved in determining if additional funding will be made to the ART include inflation rate and rate of return projections on the fund investments.  See Note 8 — Non-Nuclear Decommissioning Costs and Note 12.

Environmental Matters. TVA’s power generation activities, like those across the utility industry and in other industrial sectors, are subject to most federal, state, and local environmental laws and regulations.  Major areas of regulation affecting TVA’s activities include air quality control, water quality control, and management and disposal of solid and hazardous wastes.  In the future, regulations in all of these areas are expected to become more stringent.  Regulations are also expected to apply to new emissions and sources, with a particular emphasis on climate change, renewable generation, and energy efficiency.

TVA has incurred, and expects to continue to incur, substantial capital and operating and maintenance costs to comply with evolving environmental requirements primarily associated with, but not limited to, the operation of TVA’s coal-fired generating units.  It is virtually certain that environmental requirements placed on the operation of TVA’s coal-fired and other generating units will continue to become more restrictive and potentially apply to new emissions and sources.  Litigation over emissions or discharges from coal-fired generating units is also occurring, including litigation against TVA.  Failure to comply with environmental 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 the 1970s to 2014, TVA spent approximately $5.9 billion to reduce emissions from its power plants, including $378 million, $197 million, and $55 million in 2014, 2013, and 2012, respectively, on clean air controls.  TVA estimates that compliance with future Clean Air Act ("CAA") requirements (excluding greenhouse gas ("GHG") requirements) could lead to additional costs of $900 million from 2015 to 2025 for additional clean air controls.  There could be additional material costs if reductions of GHGs, including carbon dioxide, are mandated under the CAA or by legislation or regulation, or if future legislative, regulatory, or judicial actions lead to more stringent emission reduction requirements for conventional pollutants.  These costs cannot reasonably be predicted at this time because of the uncertainty of such potential actions.

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 is aware of alleged hazardous-substance releases at certain non-TVA areas in connection with which other potentially responsible parties may seek monetary damages from TVA.  There is information indicating that TVA sent a small amount of equipment to Ward Transformer (“Ward”), a non-TVA site in Raleigh, North Carolina.  The site is contaminated by PCBs from electrical equipment due to Ward’s practice of draining such equipment.  A working group of potentially responsible parties is cleaning up on-site contamination in accordance with an agreement with the EPA.  The cleanup effort has been divided into multiple phases, including on-site and downstream cleanup activities, two phases of soil cleanup, supplemental groundwater remediation, and cleanup of off-site contamination in the downstream drainage basin.  TVA settled its potential liability for the on-site removal action for $300 thousand and has agreed to pay approximately $8 thousand to settle its potential liability in connection with an EPA study of the site.  TVA believes that its liability for the remaining cleanup activities as well as any natural resource damages will be less than $1 million.

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TVA operations at some TVA facilities have resulted in oil spills and other contamination that TVA is addressing.  At September 30, 2014 and 2013, TVA’s estimated liability for cleanup and similar environmental work for those sites for which sufficient information is available to develop a cost estimate (primarily the TVA sites) was approximately $15 million, on a non-discounted basis, and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets.

Other. TVA is undertaking cost reduction initiatives with the goal of keeping rates low, keeping reliability high, and continuing to fulfill its broader mission of environmental stewardship and economic development. TVA’s current focus is on reducing operating and maintenance costs through further efficiency gains and streamlining the organization. The goal is to reduce TVA’s operating and maintenance costs by $500 million by 2015 as compared to its 2013 budget. As part of these cost reduction initiatives, an organizational restructuring occurred in 2014, which resulted in approximately 2,000 position reductions achieved through attrition, elimination of vacant positions, and employees leaving TVA either voluntarily or involuntarily. Certain employees were eligible for severance payments as a result of these cost reduction initiatives. As of September 30, 2014, TVA had $45 million accrued related to estimated future severance payments. See Note 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 a catastrophic event or otherwise.  

General. At September 30, 2014, TVA had accrued approximately $172 million of probable losses with respect to Legal Proceedings and estimated the range of these losses to be from $172 million to $173 million.  Of the accrued amount, $108 million is included in Other long-term liabilities and $64 million is included in Accounts payable and accrued liabilities.  TVA is currently unable to estimate any amount or any range of amounts of reasonably possible losses, and no assurance can be given that TVA will not be subject to significant additional claims and liabilities.  If actual liabilities significantly exceed the estimates made, TVA's results of operations, liquidity, and financial condition could be materially adversely affected.

Environmental Agreements. In April 2011, TVA entered into two substantively similar agreements, one with the EPA and the other with Alabama, Kentucky, North Carolina, Tennessee, and three environmental advocacy groups: the Sierra Club, the National Parks Conservation Association, and Our Children's Earth Foundation (collectively, the "Environmental Agreements”). They became effective in June 2011. Under the Environmental Agreements, TVA committed to (1) retire on a phased schedule 18 coal-fired units with a combined summer net dependable capability of 2,200 MW, (2) control, convert, or retire additional coal-fired units with a combined summer net dependable capability of 3,500 MW, (3) comply with annual, declining emission caps for SO₂ and NO_x, (4) invest $290 million in certain TVA environmental projects, (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 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, 2014 Consolidated Balance Sheet. In conjunction with the approval of the Environmental Agreements, the TVA Board determined that it was appropriate to record TVA's liabilities under the Environmental Agreements as regulatory assets, and they are included as such on the September 30, 2014 Consolidated Balance Sheet and will be recovered in rates in future periods.

Several legal and administrative clean air proceedings have already been terminated in connection with the Environmental Agreements. Additionally, the proceeding discussed below involving the John Sevier CAA permit is expected to be narrowed in scope or terminated since TVA has now retired all four of the John Sevier coal-fired units.

Legal Proceedings Related to the Kingston Ash Spill.  Seventy-eight lawsuits based on the Kingston ash spill were filed in the United States District Court for the Eastern District of Tennessee.  The plaintiffs - residents, businesses, and property owners in the Kingston area - sought unspecified compensatory and punitive damages for various tort claims, court orders to clean up properties, and other relief.  Fifteen of these lawsuits were dismissed prior to the third quarter of 2014.  On August 4, 2014, the court issued an agreed order that implements a mediated global resolution of pending claims.  Under the order, the 63 pending cases were dismissed with prejudice and TVA agreed to deposit $28 million with the court, which is responsible for disbursing the funds.  The order anticipates that further legal proceedings will be required to resolve the claims of nine of the plaintiffs, and a portion of the $28 million has been set aside under the order to cover the anticipated costs of resolving these claims.

Civil Penalty and Natural Resource Damages for the Kingston Ash Spill.  In June 2010, TDEC issued a civil penalty order of approximately $12 million to TVA for the Kingston ash spill, citing violations of the Tennessee Solid Waste Disposal Act and the Tennessee Water Quality Control Act.  Of the $12 million, TVA initially paid $10 million, and agreed to undertake

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environmental projects valued at $2 million as a credit against the remaining penalty amount. TVA completed several of those projects and has now decided to pay TDEC the remaining difference rather than do more projects. TVA has paid TDEC $750 thousand toward the remaining amount and still must pay another small amount.

Case Involving Tennessee Valley Authority Retirement System.  In March 2010, eight current and former participants in and beneficiaries of TVARS filed suit in the United States District Court for the Middle District of Tennessee against the six then-current members of the TVARS Board.  The lawsuit challenged the TVARS Board's decision to suspend the TVA contribution requirements for 2010 through 2013, and to amend the TVARS Rules and Regulations to (1) reduce the calculation for COLA benefits for CY 2010 through CY 2013, (2) reduce the interest crediting rate for the fixed fund accounts, and (3) increase the eligibility age to receive COLAs from age 55 to 60.  In September 2010, the district court dismissed this action, allowing the plaintiffs to file an amended complaint within 14 days against TVARS and TVA but not the individual directors, which the plaintiffs did shortly thereafter.  The plaintiffs allege, among other things, violations of their constitutional rights (due process, equal protection, and property rights), violations of the Administrative Procedure Act, and breach of statutory duties owed to the plaintiffs.  They seek a declaratory judgment and appropriate relief for the alleged statutory and constitutional violations and breaches of duty.  TVA filed its answer to the amended complaint in December 2010.  In May 2012, the court granted the parties' joint motion to administratively close the case subject to reopening to allow the parties the opportunity to engage in mediation. In July 2013, the court granted the plaintiffs' motion to reopen the lawsuit, and in November 2013, TVA filed a motion for summary judgment. The motion is still pending.

Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage. In June 2012, the U.S. Court of Appeals for the District of Columbia Circuit ("D.C. Circuit") vacated the NRC's updated WCD. The WCD is a generic determination by the NRC that spent nuclear fuel can be safely managed until a permanent off-site repository is established and has been a key component of the NRC licensing activities since 1984. The most recent update provided that the permanent repository would be available when necessary and that spent fuel could be stored for 60 years after a plant's license terminated. The D.C. Circuit vacated this update on the grounds that, among other things, the NRC failed to support it with an adequate National Environmental Policy Act review and the NRC did not evaluate what would happen if the repository was never built.

                In June 2012, multiple intervenor groups submitted a petition to the NRC to (1) hold in abeyance all pending reactor licensing decisions that would depend upon the WCD and (2) establish a process for ensuring that the remanded proceeding complies with the public participation requirements of Section 189a of the Atomic Energy Act.  In August 2012, the NRC issued an order (the "August 2012 NRC Order") preventing the issuance of a final licensing decision in all proceedings affected by the petition, including Watts Bar Unit 2, Sequoyah, and Bellefonte Units 3 and 4.  While resolution of unrelated contentions can proceed, the NRC stated that it will not issue final licensing decisions until it has “appropriately addressed” the D.C. Circuit decision, and all pending contentions concerning the WCD are being held in abeyance pending the NRC's completion of an environmental review and generic rulemaking addressing the shortcomings identified by the D.C. Circuit. In August 2014, the NRC issued a final rule and terminated its suspension of final licensing decisions, dismissed contentions related to the WCD pending before the NRC, and directed the Atomic Safety and Licensing Board ("ASLB") to dismiss contentions related to the WCD that were being held in abeyance.

The final rule on continued storage of spent nuclear fuel ("Continued Storage Rule") was published in the Federal Register in September 2014. Multiple intervenor groups submitted a petition to the NRC in multiple reactor licensing proceedings to suspend the issuance of final decisions in those proceedings until the NRC generically makes additional findings related to spent fuel disposal or those findings are made in individual licensing proceedings. In addition, in October 2014, attorneys general from New York, Connecticut, and Vermont filed a petition with the D.C. Circuit for review of the Continued Storage Rule. The petitioners asked the court to vacate the rule and related NRC actions and to remand the matter to the NRC for further analysis and the preparation and issuance of an environmental impact statement that complies with NEPA and other applicable laws and regulations.

Administrative Proceeding Regarding Renewal of Operating License for Sequoyah Nuclear Plant.  In May 2013, the Blue Ridge Environmental Defense League ("BREDL"), the Bellefonte Efficiency and Sustainability Team ("BEST"), and Mothers Against Tennessee River Radiation filed a petition with the NRC opposing the renewal of the operating license for Sequoyah Nuclear Plant Units 1 and 2. The petition contains eight specific contentions challenging the adequacy of the license renewal application that TVA submitted to the NRC in January 2013.  TVA filed a response with the ASLB opposing the admission of all eight of the petitioners' contentions. In July 2013, the ASLB concluded that BREDL is the only one of the three petitioners that has standing to intervene in this proceeding. The ASLB also held that seven of the contentions were inadmissible, and held one portion of the remaining contention related to WCD in abeyance pending further direction from the NRC. In September 2014, the ASLB denied BREDL's contention related to the WCD. Following the publication of the Continued Storage Rule, BREDL filed a petition with the NRC seeking suspension of the issuance of a final decision in the Sequoyah Nuclear Plant proceeding and a motion with the ASLB seeking leave to file a new, late-filed contention related to the Continued Storage Rule. See Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage.

Administrative Proceedings Regarding Bellefonte Units 3 and 4.  TVA submitted its combined construction and operating license application ("CCOLA") for two Advanced Passive 1000 reactors at Bellefonte Units 3 and 4 to the NRC in October 2007.  In June 2008, BEST, BREDL, and Southern Alliance for Clean Energy ("SACE") submitted a joint petition for intervention and a request for a hearing.  The ASLB denied standing to BEST and admitted four of the 20 contentions submitted

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by BREDL and SACE.  The NRC reversed the ASLB's decision to admit two of the four contentions, leaving only two contentions (concerning the estimated costs of the new nuclear plant and the impact of the facility's operations on aquatic ecology) to be litigated in a future hearing.  In January 2012, TVA notified the ASLB that the NRC had placed the CCOLA in “suspended” status indefinitely at TVA's request, and TVA requested that the ASLB hold the proceeding in abeyance pending a decision by TVA regarding the best path forward with regards to the CCOLA.

In July 2012, BREDL petitioned for the admission of another new, late-filed contention stemming from the D.C. Circuit's order vacating the WCD. In September 2014, the ASLB denied BREDL’s request to file the new contention. Following the publication of the Continued Storage Rule, BREDL filed a petition with the NRC seeking suspension of the issuance of a final decision in the Bellefonte Units 3 and 4 proceeding and a motion with the ASLB seeking leave to file a new, late-filed contention stemming from the Continued Storage Rule. See Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage.

Administrative Proceedings Regarding Watts Bar Unit 2.  In July 2009, SACE, the Tennessee Environmental Council, the Sierra Club, We the People, and BREDL filed a request for a hearing and petition to intervene in the NRC administrative process reviewing TVA's application for an operating license for Watts Bar Unit 2.  In November 2009, the ASLB granted SACE's request for hearing, admitted two of SACE's seven contentions for hearing, and denied the request for hearing submitted on behalf of the other four petitioners.  The ASLB subsequently dismissed one contention, leaving one aquatic impact contention.  In November 2011, TVA filed a motion for summary disposition, arguing that additional aquatic studies conducted by TVA indicate there is no longer a genuine issue of material fact in connection with SACE's remaining aquatic impact contention.  In July 2013, SACE filed a motion to withdraw its aquatic impact contention.  The ASLB has granted this motion.

In July 2012, SACE petitioned for the admission of another new, late-filed contention, similar to the one filed in the Bellefonte Units 3 and 4 proceeding, stemming from the D.C. Circuit's order vacating the WCD. In September 2014, the ASLB denied SACE’s request to file the contention related to the WCD and terminated the proceeding. Following the publication of the Continued Storage Rule, SACE filed a petition with the NRC seeking suspension of the issuance of a final decision in the Watts Bar Unit 2 proceeding and motions with the ASLB to reopen the record and for leave to file a new, late-filed contention stemming from the Continued Storage Rule. See Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage.

John Sevier Fossil Plant Clean Air Act Permit. In September 2010, the Environmental Integrity Project, the Southern Environmental Law Center, and the Tennessee Environmental Council filed a petition with the EPA, requesting that the EPA Administrator object to the CAA permit issued to TVA for operation of John Sevier. Among other things, the petitioners allege that repair, maintenance, or replacement activities undertaken at John Sevier Unit 3 in 1986 triggered the Prevention of Significant Deterioration ("PSD") requirements for SO₂ and NO_x. The CAA permit, issued by TDEC, remains in effect pending the disposition of the petition. The Environmental Agreements should narrow the scope of this proceeding. See Environmental Agreements. TVA has now retired all four John Sevier coal-fired units, and this challenge likely will not proceed.

National Environmental Policy Act Challenge at Gallatin Fossil Plant. To comply with the Environmental Agreements and the Mercury and Air Toxics Standards, TVA chose to reduce emissions at the Gallatin Fossil Plant by installing controls and an associated landfill. Pursuant to the National Environmental Policy Act ("NEPA"), TVA completed an Environmental Assessment in March 2013 to assess the impact of installing these emission controls. In April 2013, the Tennessee Environmental Council, Tennessee Scenic Rivers Association, Sierra Club, and Center for Biological Diversity filed suit in the United States District Court for the Middle District of Tennessee alleging that TVA violated NEPA when it decided to install additional emission controls and construct an associated landfill at the Gallatin Fossil Plant. Plaintiffs demand that TVA prepare an Environmental Impact Statement, and are asking the court to enjoin TVA from taking any further action relating to these matters pending compliance with NEPA. This case was transferred to the United States District Court for the Eastern District of Tennessee, and in August 2014, the court granted TVA's motion for summary judgment and dismissed all of the plaintiffs' claims. The plaintiffs did not appeal the district court’s judgment by the appeal deadline of September 30, 2014.

National Environmental Policy Act Challenge at Paradise Fossil Plant. To comply with EPA’s Mercury and Air Toxics Standards, TVA chose to retire two coal-fired units at Paradise Fossil Plant and replace them with natural gas generation. Prior to making this decision, TVA completed an Environmental Assessment in November 2013 under NEPA. In July 2014, the Kentucky Coal Association and several individuals filed suit in the United States District Court for the Western District of Kentucky alleging that TVA violated NEPA and the Energy Policy Act of 1992 in deciding to switch to natural gas generation. The plaintiffs demand that TVA prepare an Environmental Impact Statement, and are asking the court to preliminarily enjoin TVA from taking any further action relating to these matters pending compliance with NEPA. TVA has filed an opposition to the plaintiffs’ motion for a preliminary injunction as well as a motion for judgment on the administrative record. A hearing on the preliminary injunction motion is scheduled in November 2014, and briefing on TVA’s motion for judgment is ongoing.

Kingston Fossil Plant NPDES Permit Administrative Appeal.  The Sierra Club filed a challenge to the National Pollutant Discharge Elimination System ("NPDES") permit issued by Tennessee for the scrubber-gypsum pond discharge at Kingston in November 2009 before the Tennessee Board of Water Quality, Oil, and Gas ("TN Board").  TDEC is the defendant in the challenge, and TVA has intervened in support of TDEC's decision to issue the permit.  At the request of the parties, the Administrative Law Judge ("ALJ") assigned to the matter has stayed the case until October 15, 2015.  

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Bull Run Fossil Plant NPDES Permit Administrative Appeal.  SACE and the Tennessee Clean Water Network ("TCWN") filed a challenge to the NPDES permit for the Bull Run Fossil Plant in November 2010.  TDEC is the defendant in the challenge, and TVA's motion to intervene to support TDEC's decision to issue the permit was granted in January 2011.  At the contested case hearing in October 2013, the TN Board granted TDEC's and TVA's joint motion for involuntary dismissal following the conclusion of the petitioners' presentation of evidence. On December 18, 2013, TCWN and SACE filed a petition for review of the TN Board's decision in the Chancery Court for Davidson, County, Tennessee. The parties have filed appellate briefs, and oral argument is set to be heard on January 27, 2015.

Johnsonville Fossil Plant NPDES Permit Administrative Appeal.  SACE and TCWN filed a challenge to the NPDES permit for the Johnsonville Fossil Plant in March 2011.  TDEC is the defendant in the challenge.  TVA's motion to intervene was granted in August 2011. The matter has not yet been given a hearing date before the TN Board.

John Sevier Fossil Plant NPDES Permit Administrative Appeal.  SACE and TCWN filed a challenge to the NPDES permit for John Sevier in May 2011.  TDEC is the defendant in the challenge.  TVA's motion to intervene was granted in August 2011. The matter has not yet been given a hearing date before the TN Board.

Gallatin Fossil Plant NPDES Permit Administrative Appeal. SACE, TCWN, and the Sierra Club filed a challenge to the NPDES permit for the Gallatin Fossil Plant in June 2012. TDEC is the defendant in the challenge. TVA's motion to intervene was granted in September 2012. Following discovery, SACE, TCWN, and the Sierra Club voluntarily dismissed seven of the eight claims asserted in their petition. TVA moved to dismiss the remaining claim, and the ALJ assigned to the matter granted TVA’s motion and dismissed the case. On November 7, 2014, SACE, TWCN, and the Sierra Club filed a petition for review of the ALJ's dismissal in the Chancery court for Davidson County, Tennessee.

Petitions Resulting from Japanese Nuclear Events. As a result of events that occurred at the Fukushima Daiichi Nuclear Power Plant in March 2011, petitions have been filed with the NRC which could impact TVA's nuclear program. While some petitions have been dismissed after review, petitions that remain open include the following:

• Petition to Immediately Suspend the Operating Licenses of GE BWR Mark I Units Pending the Full NRC Review With Independent Expert and Public Participation From Affected Emergency Planning Zone Communities

Beyond Nuclear filed a petition in April 2011, requesting that the NRC take emergency enforcement action against all nuclear reactor licensees that operate units that use the General Electric Mark I BWR design. TVA uses this design at Browns Ferry Units 1, 2, and 3. The petition requests the NRC to take several actions, including the suspension of the operating licenses at the affected nuclear units, including Browns Ferry, until several milestones have been met. In December 2011, the NRC provided its initial response to the petition. The NRC accepted five specific requests that would apply directly or indirectly to Browns Ferry, including issues relating to spent fuel pool use and location, Mark I containment hardened vent systems and design, and backup electrical power. Each of these items was accepted for further investigation, but the requests for immediate action were rejected. The NRC has not yet rendered a decision regarding the petition.

• Twelve separate petitions on various issues

In August 2011, the Natural Resources Defense Council submitted twelve separate letters to the NRC requesting action on various health and safety aspects of operating nuclear facilities in the United States. The NRC is treating these as a single 10 CFR 2.206 Petition. The NRC closed this petition on June 17, 2014.

• Petition Pursuant to 10 CFR 2.206 - Demand For Information Regarding Compliance with 10 CFR 50, Appendix A, General Design Criterion 44, Cooling Water, and 10 CFR 50.49, Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants.

A petition was filed by the Union of Concerned Scientists in July 2011, requesting that a demand for information be issued for affected licensees, including TVA with regards to Browns Ferry, describing how the facilities comply with General Design Criterion 44, Cooling Water, within Appendix A to 10 CFR Part 50, and with 10 CFR 50.49, Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants, for all applicable design and licensing bases events. The NRC has not yet rendered a decision regarding the petition.

22. 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.  With its payment of $10 million during 2014,

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TVA fulfilled its requirement to repay $1.0 billion of its Power Program Appropriation Investment. TVA will continue to pay a return on the outstanding balance of this investment indefinitely.  See Note 17 — 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 was renewed and has a maturity date of September 30, 2015.  Access to this credit facility or other similar financing arrangements has been available to TVA since the 1960s.  See Note 13 — Credit Facility Agreements.

In the normal course of business, TVA contracts with other federal agencies for sales of electricity and other services.  Transactions with agencies of the federal government were as follows:

Related Party Transactions For the years ended, or at, September 30
	2014		2013		2012
Revenue from sales of electricity	$	128	$	120	$	117
Other income	137		102		164
Operating and maintenance	286		314		375
Cash and cash equivalents	35		38		32
Accounts receivable, net	85		58		49
Accounts payable and accrued liabilities	146		133		204
Long-term power bonds, net	3		—		—
Return on Power Program Appropriation Investment	4		7		7
Return of Power Program Appropriation Investment	10		20		20

23. Unaudited Quarterly Financial Information

A summary of the unaudited quarterly results of operations for the years 2014 and 2013 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 2014
	First			Second		Third			Fourth		Total
Operating revenues	$	2,382		$	2,938	$	2,651		$	3,166	$	11,137
Operating expenses	2,164			2,362		2,453			2,569		9,548
Operating income	218			576		198			597		1,589
Net income (loss)	(67		)	295		(81		)	322		469

Unaudited Quarterly Financial Information 2013
	First			Second		Third			Fourth		Total
Operating revenues	$	2,579		$	2,741	$	2,602		$	3,034	$	10,956
Operating expenses	2,523			2,380		2,324			2,276		9,503
Operating income	56			361		278			758		1,453
Net income (loss)	(245		)	54		(12		)	474		271

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Report of Independent Registered Public Accounting Firm

The Board of Directors of Tennessee Valley Authority

We have audited the accompanying consolidated balance sheets of Tennessee Valley Authority as of September 30, 2014 and 2013, and 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, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Tennessee Valley Authority at September 30, 2014 and 2013, and the consolidated results of its operations and its cash flows for each of the three years in the period ended September 30, 2014, 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), Tennessee Valley Authority's internal control over financial reporting as of September 30, 2014, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (1992 framework) and our report dated November 14, 2014 expressed an unqualified opinion thereon.

/s/ Ernst & Young LLP

Chattanooga, Tennessee

November 14, 2014

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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 Securities Exchange Act of 1934 (the "Exchange Act")) as of September 30, 2014.  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, 2014, 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 controls 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, 2014, based on the framework in Internal Control — Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO").  Based on this evaluation, TVA’s management concluded that TVA’s internal control over financial reporting was effective as of September 30, 2014.

Although management’s report on 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, 2014, 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

The Board of Directors of Tennessee Valley Authority

We have audited Tennessee Valley Authority’s internal control over financial reporting as of September 30, 2014, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (1992 framework) (the COSO criteria). Tennessee Valley Authority’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 conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). 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.

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.

In our opinion, Tennessee Valley Authority maintained, in all material respects, effective internal control over financial reporting as of September 30, 2014, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Tennessee Valley Authority as of September 30, 2014 and 2013, and 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, 2014 of Tennessee Valley Authority and our report dated November 14, 2014 expressed an unqualified opinion thereon.

/s/ Ernst & Young LLP

Chattanooga, Tennessee

November 14, 2014

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ITEM 9B.  OTHER INFORMATION

On November 13, 2014, Mr. Johnson approved compensation adjustments for the following Named Executive Officers for 2015:

• The salary for Mr. Pardee will increase from $620,000 to $645,000, and Mr. Pardee will be granted an award of $200,000 under TVA’s Long-Term Retention Incentive Plan (“LTRIP”) on January 1, 2015. Mr. Pardee will be vested in and receive payment of the full award on December 31, 2017, as long as he remains employed with TVA on that date.

• The salary for Mr. Thomas will increase from $550,000 to $575,000, and Mr. Thomas will be granted two awards under TVA’s LTRIP. Each award will be $200,000 and will be granted on January 1, 2015. Mr. Thomas will be vested in and receive payment of the full awards under the grants on December 31, 2016, and December 31, 2017, respectively, as long as he remains employed with TVA on those dates. Mr. Johnson also approved an arrangement under which Mr. Thomas will be eligible to receive $200,000 on December 31, 2015, as long as he remains employed with TVA on that date.

• The salary for Mr. Grimes will increase from $535,000 to $555,000, and Mr. Grimes will be granted an award of $150,000 under TVA’s LTRIP on January 1, 2015. Mr. Grimes will be vested in and receive payment of the full award on December 31, 2017, as long as he remains employed with TVA on that date.

• The salary for Mr. Skaggs will increase from $431,600 to $445,000, and Mr. Skaggs will be granted an award of $150,000 under TVA’s LTRIP on January 1, 2015. Mr. Skaggs will be vested in and receive payment of the full award on December 31, 2017, as long as he remains employed with TVA on that date.

The salary adjustments described above became effective as of October 1, 2014. No adjustments were made to any other existing elements of compensation for these Named Executive Officers for 2015.

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PART III

ITEM 10.  DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

Directors

TVA is administered by a board of nine part-time members appointed by the President of the United States with the advice and consent of the U.S. Senate.  The Chair of 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 United States 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 United States, 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.

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, 2014, consisted of the following eight individuals with their ages and terms of office provided:

Directors	Age	Year Current Term Began	Year Term Expires
Joe H. Ritch, Chair	64	2013	2016
Barbara S. Haskew	74	2010	2014(1)
Richard C. Howorth	63	2011	2015
William B. Sansom	73	2010	2014(1)
Marilyn A. Brown	65	2013	2017
V. Lynn Evans	61	2013	2017
C. Peter Mahurin	76	2013	2016
Michael R. McWherter	58	2013	2016

Notes

(1) Although the terms of these directors expired in May 2014, they were 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. Ritch of Huntsville, Alabama, joined the TVA Board in January 2013, and began serving as Chair of the TVA Board in May 2014. He has been an attorney at the Sirote & Permutt, PC law firm in Huntsville, Alabama, since 1982. He has been a director of Axometrics, which designs and manufactures Mueller Matrix polarization testing for LCD panels, since 2004. He has also served as Chair of the Tennessee Valley Base Realignment and Closure Committee since 1994, as Co-Chair of the Tennessee Valley Growth Coordination Group since 2008, and as a board member of the Von Braun Center for Innovative Science since 2006. He was a member of the University of Alabama System Board of Trustees from 2005 to 2011.

Dr. Haskew of Chattanooga, Tennessee, joined the TVA Board in October 2010. Dr. Haskew began working at Memphis State University in 1965. She joined Middle Tennessee State University ("MTSU") in 1970 and chaired the Department of Economics and Finance from 1974 until 1980. In 1980 she left MTSU and managed the TVA Rate Staff for eight years. Dr. Haskew returned to MTSU in 1988 and served as Dean of the College of Business until her appointment as Provost and Vice President for Academic Affairs in 1995. She retired from MTSU in August 2010. Dr. Haskew is a labor and employment arbitrator on the rosters of the American Arbitration Association and the Federal Mediation and Conciliation Service.

Mr. Howorth of Oxford, Mississippi, joined the TVA Board in July 2011. 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.  

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Mr. Sansom of Knoxville, Tennessee, served on the TVA Board from March 2006 until December 2009, was Chair of the TVA Board from March 2006 until May 2009, and began a second term on the TVA Board in October 2010.  He was elected Vice Chair of the TVA Board in April 2011, and served as Chair from January 2012 to May 2014.  Mr. Sansom is Chair and Chief Executive Officer of the H.T. Hackney Co., a diversified company involved in the wholesale grocery and furniture manufacturing businesses, and has held that position since 1983.  Since 1995, Mr. Sansom has also been a director of Astec Industries, Inc., a corporation based in Chattanooga, Tennessee, that manufactures equipment and components used in road construction, and since 1984, he has been a director at First Horizon National Corporation, a Memphis, Tennessee, bank holding company.  In 2006, he was named director of Mid-America Apartment Communities, Inc., a real estate investment trust with ownership interests in apartment homes.  From 1994 to 2006, he was a director of Martin Marietta Materials, Inc., a company based in Raleigh, North Carolina, that is in the construction material business.

Dr. Brown of Atlanta, Georgia, served on the TVA Board from October 2010 to January 2013 and began a second term on the TVA Board in September 2013.  Dr. Brown has been a Professor in the School of Public Policy at Georgia Institute of Technology in Atlanta, Georgia, since August 2006.  From 1984 to August 2006, Dr. Brown worked at the Oak Ridge National Laboratory ("ORNL") in Oak Ridge, Tennessee.  At ORNL, she was Deputy Director and Acting Director of the Engineering Science and Technology Division (from 2005 to 2006) and Program Director of the Energy Efficiency and Renewable Energy Program (from 2000 to 2005). Dr. Brown served from 2006 until 2009 as a member of the Board of Directors of the Southeast Energy Efficiency Alliance, serving as Board Chair from 2006 until 2008. She served as a member of the Board of Directors of the American Council for an Energy-Efficient Economy from 2002 until 2009. From 2002 until 2009, Dr. Brown was a commissioner on the National Commission on Energy Policy. She served as a member of the Board of Directors of the Alliance to Save Energy from 2000 through 2009.

Ms. Evans of Memphis, Tennessee, joined the TVA Board in January 2013. She has been the owner of V. Lynn Evans, CPA, a certified public accounting and consulting firm in Memphis, Tennessee, since 1983. Ms. Evans was a board member of Memphis Light, Gas, and Water Division, a TVA local power company customer, from 2004 to January 2013, and served as Chair from January 2008 to December 2009. She has been a director of community-based First Alliance Bank in Memphis, Tennessee, since its inception in 1998, holding various positions, including Chair of the audit committee and loan committee member. Ms. Evans has also served in leadership positions in a number of community organizations, including as a board member of ArtsMemphis from 1995 to 2008, Community Foundation of Greater Memphis from 1995 to 2004 and from 2006 to present, the RISE Foundation from 1997 to 2007, and the Women's Foundation for a Greater Memphis from 1999 to 2001. Ms. Evans is a member of the American Institute of Certified Public Accountants and the Tennessee Society of Certified Public Accountants (Memphis Chapter).

Mr. Mahurin of Bowling Green, Kentucky, joined the TVA Board in January 2013. He has been Chair of Hilliard Lyons Financial Services, a financial services firm based in Louisville, Kentucky, since 2008. Mr. Mahurin has worked for Hilliard Lyons in various capacities since 1968. Mr. Mahurin has been a director of Houchens Industries, Inc., a diversified conglomerate based in Bowling Green, Kentucky, since 1992; Gray Construction, an engineering, design and construction company based in Lexington, Kentucky, since 2007; Albany Bancorp, Inc., a bank holding company based in Albany, Kentucky, since 1992; First Cecilian Bancorp, a bank holding company based in Cecilia, Kentucky, since 1997; and Jackson Financial, a bank holding company based in Mayfield, Kentucky, since 2007. He is also a board member of the Governor's Scholars of Kentucky.

Mr. McWherter of Jackson, Tennessee, joined the TVA Board in January 2013. He has been the owner and president of Central Distributors, Inc., and Volunteer Distributing Company Inc., both Tennessee-based beverage distribution companies, since 1989 and 1986, respectively. He has been a director of First State Bank, a bank holding company in Union City, Tennessee, since 2002, and served as Chair from 2007 to 2009. He also served as Chair of the First State Bank Audit Committee from 2007 to 2009. He served as a director·of the Jackson Energy Authority, a TVA local power company customer, from 2007 to January 2013. Mr. McWherter has also served in leadership positions in a number of community organizations, including as a board member of the Tennessee Performing Arts Center from 1988 to 1995, a director of the Jackson Chamber of Commerce from 1990 to 1996, a director of the Nashville Arts Council from 1982 to 1985, and a member of the Tennessee Executive Residence Preservation Foundation Board from 2002 to 2010.

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Executive Officers

TVA’s executive officers as of November 14, 2014, their titles, their ages, and the date their employment with TVA commenced are as follows:

Executive Officers	Title	Age	Employment Commenced
William D. Johnson	President and Chief Executive Officer	60	2013
Joseph P. Grimes, Jr.	Executive Vice President and Chief Nuclear Officer	58	2013
Van M. Wardlaw	Executive Vice President, External Relations and Interim Senior Vice President, Shared Services	54	1982
Charles G. Pardee	Executive Vice President and Chief Operating Officer	54	2013
Ralph E. Rodgers	Executive Vice President and General Counsel	60	1979
John M. Thomas, III	Executive Vice President and Chief Financial Officer	50	2005
Katherine J. Black	Senior Vice President of Human Resources and Communications	59	1986
Michael D. Skaggs	Senior Vice President, Watts Bar Operations and Construction	54	1994
Diane T. Wear	Vice President and Controller (Principal Accounting Officer)	46	2008

Mr. Johnson has served as TVA's President and Chief Executive Officer since January 2013. Mr. Johnson served as Chair, President and Chief Executive Officer of Progress Energy, Inc. ("Progress Energy"), an electric utility based in Raleigh, North Carolina, from October 2007 to July 2012. During this time, Mr. Johnson also served as the Chair of Progress Energy Carolinas, Inc., and Progress Energy Florida, Inc., both of which are subsidiaries of Progress Energy. Mr. Johnson held a number of other positions before he became Chair and CEO of Progress Energy, including President and Chief Operating Officer of Progress Energy; Group President for Energy Delivery; President and Chief Executive Officer for Progress Energy Service Company, LLC; and General Counsel and Corporate Secretary for Progress Energy. Mr. Johnson joined Carolina Power & Light Company ("CP&L"), a predecessor to Progress Energy, in 1992. Before joining CP&L, Mr. Johnson was a partner with the Raleigh, North Carolina, law office of Hunton & Williams LLP, where he specialized in the representation of utilities.

Mr. Grimes was named TVA's Executive Vice President and Chief Nuclear Officer in July 2013.  Before joining TVA, Mr. Grimes worked at Exelon Nuclear and held a variety of positions there, including Senior Vice President, Engineering and Technical Services, Exelon Nuclear Fleet (from 2011 to 2013), Senior Vice President, Mid-Atlantic Operations (from 2009 to 2011), and Site Vice President at Peach Bottom Nuclear Station (from 2007 to 2008). Mr. Grimes joined Exelon Nuclear in 1979.

Mr. Wardlaw was named Executive Vice President, External Relations in July 2014 and was additionally named Interim Senior Vice President, Shared Services in September 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. Pardee joined TVA in April 2013 as Executive Vice President and Chief Generation Officer, and he was named Executive Vice President and Chief Operating Officer in September 2013. Mr. Pardee worked at Exelon Corporation, an energy company, and its subsidiaries from February 2000 to November 2012. He served as Chief Operating Officer, Exelon Generation from April 2010 to November 2012, as Chief Nuclear Officer, Exelon Nuclear from October 2007 to April 2010, as Chief Operating Officer, Exelon Nuclear from June 2005 to October 2007, as Senior Vice President, Nuclear Fleet Services from August 2003 to June 2005, as Senior Vice President, Mid-Atlantic Operations from January 2002 to August 2003, and as Site Vice President, LaSalle County Generation Station from February 2000 to January 2002.

Mr. Rodgers was named TVA's Executive Vice President and General Counsel in July 2011.  He served as Acting General Counsel from April 2010 to July 2011, as Deputy General Counsel from January 2010 to April 2010, as Assistant General Counsel from February 2001 to January 2010, and as an attorney from June 1979 to March 1986 and from June 1987 to February 2001. Mr. Rodgers has announced his intent to retire at the end of calendar year 2014.

Mr. Thomas has served as TVA's Chief Financial Officer 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 Chief Financial Officer 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.

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Ms. Black was named TVA’s Senior Vice President of Human Resources and Communications in September 2013. She previously served as Vice President of Human Resources from October 2010 to September 2013 and Director of Employee Relations from February 2010 to April 2011. Before being selected as Vice President, Ms. Black served in several human resources positions. Prior to joining TVA in 1986, Ms. Black served in the U.S. Army.

Mr. Skaggs was named Senior Vice President, Watts Bar Operations and Construction in September 2013. Since joining TVA in 1993 as Manager of Projects at Watts Bar Nuclear Plant, Mr. Skaggs has held several management positions, including Senior Vice President, Nuclear Construction (February 2012 to September 2013), Senior Vice President of Nuclear Generation Development and Construction (October 2011 to February 2012), Site Vice President of Sequoyah Nuclear Plant (November 2010 to October 2011), Vice President of Nuclear Operations Support (December 2009 to November 2010), Site Vice President at Watts Bar Nuclear Plant (July 2005 to December 2009), and Site Vice President at Browns Ferry Nuclear Plant (July 2004 to July 2005).

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 Chief Executive Officer, Chief Financial Officer, 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 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 V. Lynn Evans, Marilyn A. Brown, Joe H. Ritch, and Mike R. McWherter.

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

•Nuclear Oversight Committee

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ITEM 11.  EXECUTIVE COMPENSATION

Compensation Discussion and Analysis

The following Compensation Discussion and Analysis describes TVA's compensation philosophy and the policies and decisions that guided compensation for TVA’s named executive officers in 2014. The 2014 Named Executive Officers are as follows:

• William D. Johnson, President and Chief Executive Officer ("CEO");

• Charles G. Pardee, Executive Vice President and Chief Operating Officer ("COO");

• John M. Thomas, III, Executive Vice President and Chief Financial Officer ("CFO");

• Joseph P. Grimes, Jr., Executive Vice President and Chief Nuclear Officer ("CNO"); and

• Michael D. Skaggs, Senior Vice President, Watts Bar Operations and Construction.

Detailed compensation information for these executives is contained in the Summary Compensation Table.

Executive Summary

Based on its annual performance and productivity, TVA rewards employees through its Winning Performance Team Incentive Plan ("WPTIP") and Executive Annual Incentive Plan ("EAIP"). Similar to incentive programs at other utilities, awards are not part of base pay but are “at risk” because employees must earn them each year by reaching or exceeding specific targets.

At the onset of 2014, President and CEO Bill Johnson challenged employees to work together as a unified team to improve TVA performance. Employees aligned around the TVA mission, strategic imperatives, and 2014 priorities and business goals, and metrics were established for the enterprise as well as individual business units. This alignment, combined with increased collaboration across the enterprise, resulted in strong operational and financial performance for the year.

To reflect the collaborative effort undertaken by TVA’s business units to achieve TVA’s overall strategic priorities and business goals for the year, the payout range for these annual plans across business units for 2014 was narrowed.

In addition, the TVA Board adjusted the 2014 payouts under the Executive Long-Term Incentive Plan ("ELTIP") from 91.30 percent to 100 percent in recognition of TVA's overall good performance and financial discipline in 2014 and wholesale rate unfavorability being driven by factors outside of management's control.

Compensation Plan

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 (“Compensation Plan”) as adopted by the TVA Board in accordance with guidance of the TVA Act. The Compensation Plan is designed to:

• Provide market-based, competitive compensation levels so TVA can attract, retain, and motivate highly competent employees. Total direct compensation generally targets the 50th percentile of the relevant labor market, although some positions, such as those requiring certain nuclear expertise, are targeted 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 Named Executive Officers, is tied to performance improvement. At least half (and in some cases more than two-thirds) of each Named Executive Officer’s direct compensation opportunity is delivered through performance-based incentive programs.

• Align the organization’s short- and long-term goals and objectives with compensation by providing a mix of salary and performance-based annual 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 prevailing compensation for similar positions in private industry, including engineering and electric utility companies, publicly-owned electric utilities, and federal, state, and local governments; and

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

Consistent with these requirements, the compensation programs for the Named Executive Officers under the Compensation Plan include the following:

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Compensation Program Components for Named Executive Officers
Compensation Component	Objective	Key Features
Annual Salary	Fixed base compensation to executives	Annual salary is targeted at 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 past years (except those years impacted by the federal salary freeze), salary has been typically reviewed annually to consider changes in peer group benchmark salaries and/or exceptional individual merit performances.
Executive Annual Incentive Plan ("EAIP")	Not-guaranteed, variable, and based on the attainment of pre-established performance goals for the fiscal year	Annual incentive payouts are based on the results of established goals of each strategic business unit scorecard, as determined from year to year by the TVA Board. Annual incentive payouts may be impacted by a corporate multiplier or adjusted by the TVA Board or CEO, as appropriate, based on the evaluation of performance during the year. Target annual incentive opportunities increase with position and responsibility and are based on the opportunities other companies in TVA's peer group provide to those in similar positions. Annual incentive opportunities are reviewed annually to consider changes in peer group benchmark short-term incentives.
Executive Long-Term Incentive Plan ("ELTIP")	Not-guaranteed, variable, and based on the attainment of pre-established performance goals of a performance cycle, typically three fiscal years	Participation is limited to executives in critical positions who make decisions that significantly influence developing and attaining TVA's long-term strategic objectives. Long-term incentive payouts are based on achievement of performance goals established for a specific, three-year performance cycle and may be adjusted by the TVA Board, based on the evaluation of performance during the cycle. Long-term incentive opportunities are reviewed annually for the next three-year performance cycle to consider changes made in their long-term incentives by companies in TVA's peer group.
Long-Term Deferred Compensation Plan ("LTDCP")	Awarded in the form of annual credits that vest after a specified period of time, typically three to five years	Awarded to provide retention incentives to executives similar to those provided by restricted stock or restricted stock units in publicly traded companies. Executives generally must remain at TVA for the entire length of the agreement to receive compensation credits. Long-term deferred compensation is reviewed annually and credits are targeted to approximately 20 - 30 percent of total long-term compensation.
Long-Term Retention Incentive Plan ("LTRIP")	New retention-oriented plan was implemented in 2014; similar to the Long-Term Deferred Compensation Plan	Awarded to provide retention incentives to executives similar to those provided by restricted stock or restricted stock units in publicly-traded companies. Grants will vest after a specified period of time, usually no longer than three years. Intended to provide approximately 20 - 30 percent of total long-term incentive opportunity. The plan is intended to substantially replace the LTDCP as currently outstanding LTDCP credits expire.
Total Direct Compensation	Annual Salary plus Annual Incentive Compensation plus Long-Term Incentive Compensation plus Long-Term Deferred Compensation plus Long-Term Retention Incentive	Total direct compensation (salary plus annual and long-term incentive compensation plus long-term deferred compensation plus long-term retention incentive) is targeted at the median (50th percentile) level 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, or other business reasons.
Pension Plans ("Qualified Plans and Supplemental Executive Retirement Plan")	Both qualified and supplemental, which provide compensation beginning with retirement or termination of employment (if vesting requirements are satisfied)	Broad-based plans available to full-time employees of TVA that are qualified under 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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Assessment of Risk

TVA's Enterprise Risk Management organization evaluates potential risk associated with the Compensation Plan and TVA's executive and non-executive compensation policies and practices. For 2014, the evaluation found no risk associated with the Compensation Plan and TVA's executive and non-executive compensation policies and practices that is reasonably likely to have a material adverse effect on TVA.

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 Named Executive Officers. The TVA Board is directed under Section 2 of the TVA Act to establish a plan that specifies all compensation (such as salary or any other pay, benefits, incentives, and any 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 or other pay, benefits, incentives, and any other form of remuneration) for all managers and technical personnel who report directly to the CEO (including any adjustment 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 United States Government ($157,100 in 2014); and

• The CEO will determine the salary and benefits of employees whose annual salary is not greater than Level IV of the Executive Schedule ($157,100 in 2014).

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 action for which the TVA Board is responsible but has not reserved for itself. The TVA Board has taken additional action to delegate authority with respect to executive compensation, as follows:

• The TVA Board has approved for the direct reports to the CEO compensation ranges of 80 percent to 110 percent of the targeted total direct compensation for comparable positions. These targeted levels of total direct compensation are consistent with the Compensation Plan and with external benchmarking sources. The TVA Board has also authorized the CEO to set or adjust compensation for present or future direct reports within such compensation ranges, 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 Chair of the TVA Board, 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 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.

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 2014. 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 Chair of the TVA Board 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 Executive Annual Incentive Plan, 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 has selected independent consulting firm Towers Watson to help evaluate competitive compensation. The Committee assessed certain independence factors and determined the firm’s work raised no potential conflict of interest.

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Use of Market Data and Benchmarking

TVA generally targets total direct compensation for executives at a competitive level based on the relevant labor market. After compiling competitive market compensation for the positions at the beginning of 2014, the Committee, with assistance from Towers Watson, used the information to:

• Test target compensation level and incentive opportunity competitiveness; and

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

TVA's relevant labor market for most executives, including the Named Executive Officers, comprised both private and publicly-owned companies in the energy services industry of similar revenue and scope to TVA. For the survey-based analysis, TVA used the 2013 Towers Watson Energy Services Executive Compensation Database to look at the following energy-services companies with annual revenues greater than $6.0 billion:

AES Corp.	Duke Energy Corp.	NextEra Energy, Inc.
Ameren Corp.	Edison International	Northeast Utilities
American Electric Power Co., Inc.	Energy Future Holdings Corp.	Pacific Gas and Electric Co.
CenterPoint Energy, Inc.	Entergy Corp.	PPL Corp.
CMS Energy Corp.	Exelon Corp.	Public Service Enterprise Group Inc.
Consolidated Edison, Inc.	FirstEnergy Corp.	Sempra Energy
Dominion Resources, Inc.	IPR-GDF SUEZ North America	Southern Company
DTE Energy Co.	MidAmerican Energy Holding	Xcel Energy Inc.

 For the analysis of proxy statements and annual reports on Form 10-K, TVA looked at all companies in the peer group above, as well as four additional companies in the energy services industry (Calpine Corp., NiSource Inc., NPG Energy, and Pepco Holdings Inc.), as recommended by Towers Watson. These companies were added to the analysis because they are energy services firms with annual revenues between one-half and two times TVA's revenue, but either did not participate in the 2013 Towers Watson Energy Services Executive Compensation Survey or reported an annual revenue for 2013 that fell slightly short of $6 billion.

In addition, TVA informally considered the following companies with revenues between $3.0 billion and $6.0 billion that participated in the 2013 Towers Watson Energy Services Executive Compensation Survey: Alliant Energy Corp; Integrys Energy Group; MDU Resources; OGE Energy; Pinnacle West Capital; Puget Energy Inc.; SCANA Corp.; TECO Energy; and Wisconsin Energy Corp.

The following government entities that participated in the 2013 Towers Watson Energy Services Executive Compensation Survey were also informally considered by the Committee: Colorado Springs Utilities; CPS Energy; ElectriCities of North Carolina; Energy Northwest; Grand River Dam Authority; New York Power Authority; Omaha Public Power; and Salt River Project. Each of these government entities has annual revenue of less than $3.0 billion.

Executive Compensation Program Components

Salary. In December 2010, Congress passed the Continuing Appropriations and Surface Transportation Extensions Act of 2011, which included a two-year freeze on statutory pay adjustments for all executive branch pay schedules and a two-year freeze by executive agencies on base salary increases for all senior executives. These two-year freezes applied to calendar years 2011 and 2012. The TVA Board members were covered by the first freeze and TVA officers (Vice President level and above), including the Named Executive Officers, were covered by the second freeze. Congress passed a Continuing Resolution (H.J. Res. 117) in September 2012 that extended the federal employee salary freezes through March 27, 2013, and in March 2013, passed a stop-gap spending bill that extended the freezes through December 31, 2013. Accordingly, TVA officers, including the Named Executive Officers, did not receive a salary increase, except for promotions, for calendar years 2011, 2012, and 2013. In December 2013, an executive order was signed to allow federal agencies to update their pay systems. On January 13, 2014, TVA provided base salary increases to manager, specialist, and excluded employee populations. Three Named Executive Officers received base salary increases on February 10, 2014. Salary increases were awarded based on prior year performance, and adjustments were made to bring their base salaries into alignment with the market.

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    The salaries of the Named Executive Officers for 2014 and 2013 were as follows:  

Executive	2014(1)	2013
Mr. Johnson	$950,000	$950,000
Mr. Pardee	$620,000	$590,000
Mr. Thomas	$550,000	$520,000
Mr. Grimes	$535,000	$535,000(2)
Mr. Skaggs	$431,600	$415,000

Notes

(1) The new salaries became effective on February 10, 2014.

(2) Mr. Grimes did not receive an increase to base salary. His hire date of August 26, 2013, precluded him from eligibility.

More information about the approval of Mr. Johnson's compensation for 2014 is below. See Considerations Specific to Mr. Johnson.

Annual Incentive Compensation. All executives, including the Named Executive Officers, participate in the EAIP. The EAIP is designed to encourage and reward executives for successfully achieving annual financial and operational goals. For 2014, the EAIP focused on achieving strategic business unit goals. The specific award opportunities, metrics, and associated goals are described below.

Annual incentive opportunities for participants in the EAIP generally increase with position and responsibility. For 2014, the TVA Board set Mr. Johnson's target EAIP award opportunity at 100 percent of salary. See Considerations Specific to Mr. Johnson. In February 2014, Mr. Johnson evaluated the appropriateness of the EAIP award opportunities for Mr. Thomas, Mr. Pardee, Mr. Grimes, and Mr. Skaggs and made no changes. Accordingly, target EAIP award opportunities of the Named Executive Officers for 2014 were as follows:

Named Executive Officers	Target Annual Incentive Opportunity(1)
Mr. Johnson	100%
Mr. Pardee	80%
Mr. Thomas	80%
Mr. Grimes	80%
Mr. Skaggs	70%
(1) Represents a percent of each Named Executive Officer’s salary.

The TVA Board established seven different organizational scorecards for the 2014 EAIP (TVA Corporate, Operations, Nuclear Operations, Power Operations, Projects, Transmission, and Nuclear Construction). These scorecards are also used to determine annual incentive payouts for all non-executive TVA employees who participated in TVA's 2014 Winning Performance Team Incentive Plan ("WPTIP"). The Named Executive Officers are on four different scorecards, and their goals and associated weightings are outlined below:

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TVA 2014 Organization Scorecards
						Goals
Performance Measure	Corporate Scorecard (Johnson, Thomas)	Operations Scorecard (Pardee)	Nuclear Operations Scorecard (Grimes)	Nuclear Construction Scorecard (Skaggs)	Results Achieved	Threshold (50%)	Target (100%)	Maximum (150%)
Corporate Total Spending(1)	40%				$837	$905	$884	$864
Nuclear Operating Availability Factor (%)(2)	20%	25%	25%	20%	96.7%	96.1%	97.0%	97.9%
Coal Seasonal Equivalent Forced Outage Rate (%)(3)	15%	20%	15%	15%	5.4%	6.3%	5.1%	3.2%
Combined Cycle Seasonal Equivalent Forced Outage Rate (%)(4)	5%	10%	5%	5%	1.1%	4.0%	2.7%	1.4%
Load Not Served (System Minutes)(5)	10%	15%	10%	10%	4.0	7.8	5.3	3.1
Reportable Environmental Events(6)	10%	10%	10%	10%	10	21	17	12
Operations Total Spending(7)		20%			$3,473	$3,826	$3,719	$3,612
Nuclear Operations Total Spending(8)			20%		$1,252	$1,362	$1,330	$1,297
Nuclear Operations Equipment Reliability Index(9)			15%		90	81	85	89
Nuclear Construction Total Spending(10)				20%	$776	$817	$786	$755
Watts Bar Construction Milestones(11)				20%	16	13	15	17
	100%	100%	100%	100%

Notes (dollar amounts shown in millions)

(1) Corporate Total Spend is defined as Non-fuel Operating & Maintenance ("O&M") expenses and total capital expenses for corporate organizations.

(2) Nuclear Operating Availability Factor ("OAF") is calculated as follows: (Winter Net Dependable Capacity x Period Hours - Total Megawatt Hour Losses) (Winter Net Dependable Capacity x Period Hours - Planned Outage Megawatt Hour Losses (Refueling Outages Only)).

(3) Coal Seasonal Equivalent Forced Outage Rate measures the generation lost because of forced events as a percentage of time a unit would have been scheduled to run. This indicator is for the months of December to March and June to September and includes the Allen, Cumberland, Gallatin, Paradise, and Shawnee coal-fired plants.

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(4) Combined Cycle Seasonal Equivalent Forced Outage Rate measures the generation lost because of forced events as a percentage of time a unit would have been scheduled to run. This indicator is for combined cycle plants for the months of December to March and June to September.

(5) Load not Served is a measure of the magnitude and duration of transmission system outages that affect TVA customers and is expressed in system minutes.

(6) A Reportable Environmental Event ("REE") is an environmental event at a TVA facility or elsewhere caused by TVA or TVA contractors that violates permit conditions or other regulatory requirements and triggers regulatory required oral or written notification to or enforcement action by a regulatory agency. Multiple parameters or multiple media/regulatory violations that result from the same root cause/event are counted as one REE. However, repeat occurrences count as separate REEs if they occur in a different reporting period.

(7) Operations Total Spending includes Non-fuel O&M production expenses and total capital expense for the entire Operations organization.

(8) Nuclear Operations Total Spending consists of O&M and capital expenses excluding fuel and inventories.

(9) Nuclear Operations Equipment Reliability Index consists of leading and lagging indicators of nuclear equipment reliability measuring operational performance, safety system performance, maintenance and work management, and planning/monitoring.

(10) Nuclear Construction Total Spend includes all O&M and capital expenses within Nuclear Construction.

(11) Watts Bar Construction Milestones are major components of work which need to be accomplished to complete Watts Bar Unit 2 projects on or before scheduled completion.

The results of the TVA 2014 organization scorecards applicable to the Named Executive Officers are as follows:

TVA Scorecard Assignment & Results (% of Opportunity Achieved)
Named Executive Officer	Scorecard	Overall Percent of Opportunity Achieved	Adjusted Results
William D. Johnson	Corporate	125.25%	123.00%
John M. Thomas, III
Charles G. Pardee	Operations	117.77%	120.75%
Joseph P. Grimes, Jr.	Nuclear Operations	121.91%	120.75%
Michael D. Skaggs	Nuclear Construction	113.47%	118.00%

Once scorecard results were calculated, the CEO, after informing the TVA Board, made adjustments to the scorecards based on the following considerations:

• Payout percentage reflects a successful 2014

• Adjustment emphasizes shared performance and overall combined effort

• Adjustment considers the comparable level of target challenge within scorecards

In August 2013, the TVA Board approved a corporate multiplier for the WPTIP and EAIP plans to be implemented in 2014. The TVA Board defined key strategic imperatives to be included in the multiplier (between 0 and 1.0) and examined performance with the CEO in these areas. Performance was assessed using discretion to determine the magnitude of any necessary adjustments. The multiplier, which can only be used in terms of reduction, was applied to organizational scorecard results.

The following considerations were noted by the TVA Board in recommending a multiplier amount of 1.00:

• Top decile safety performance

• Strong financial performance driven by O&M efficiency, debt reduction, and cold winter

• Record setting economic performance

• Notable significant events:

•Polar vortex

•Improved nuclear performance

•Lazard validation of TVA model

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TVA Corporate Multiplier
Performance Measure	Results Achieved	Target
Safety - Recordable Incident Rate (RIR)(1)	0.52	0.00
Total Financing Obligations (TFO) ($ Billions)(2)	$26.1	$28.4
Operating Cash Flow ($ Millions)(3)	$2,980	$2,230
Net Income ($ Millions)(4)	$469	$1
Jobs Created and Retained(5)	60,378	50,000
Board Level Significant Events(6)	0	0
Recommended Corporate Multiplier of	1.00

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.

(2) Total Financing Obligations include all statutory debt and other financing obligations.

(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.

(4) Net Income consists of the organization’s net earnings derived from taking revenues and adjusting for the cost of doing business, including the cost of sales, depreciation, interest, taxes, and other expenses.

(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) TVA Board Level Significant Events include items deemed materially significant to the TVA Board of Directors and that affect TVA’s reputation with its customers and its stakeholders, the organizational health of the workforce, or its impact on the public at large.

For 2014, 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 Subjective Individual Assessment

For EAIP participants, including the Named Executive Officers, the percent of opportunity achieved was calculated based on performance of one of seven organizational scorecards.

As discussed above, the corporate multiplier in 2014 ranged from 0 to 1.00 and allowed the TVA Board to adjust the scorecard achievement results based on several metrics and other factors. The TVA Board determined that no adjustment would be made using the corporate multiplier.

The 2014 EAIP maintained the CEO's discretion to adjust individual incentive awards based on subjective assessments of individual performance during 2014. In addition, the Chair of the TVA Board, in consultation with the Committee and with input from individual TVA Board members, will continue to evaluate the CEO’s performance to determine adjustments to his incentive award under the EAIP.

At the end of 2014, the Chair of the TVA Board, in consultation with the Committee and with input from individual members of the TVA Board, evaluated Mr. Johnson’s performance as CEO during 2014. Based on this review, the Chair of the TVA Board decided that Mr. Johnson's final annual incentive award should be paid as achieved.

Once all other preliminary 2014 EAIP payouts were calculated and the corporate multiplier was applied, the CEO evaluated each participant's performance (except his own) to determine whether any upward or downward adjustment should be made to the final annual incentive award of the participants, including each Named Executive Officer. The individual performance evaluations were conducted by the CEO for his direct reports, or each participant's supervisor, in consultation with the CEO, based on a subjective review of how the participant performed during the year and/or how the business unit over which the participant had responsibility performed.

Pursuant to TVA Board delegations described above, Mr. Johnson, as CEO, in consultation with the Committee and with input from individual members of the TVA Board, subjectively evaluated the performance of Mr. Pardee and Mr. Thomas as

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his direct reports during 2014. Mr. Johnson, with input from individual members of the TVA Board, determined that these awards should be paid as achieved for his direct reports.

Mr. Johnson and Mr. Pardee, TVA's Executive Vice President and Chief Operating Officer (to whom Mr. Grimes reported), subjectively evaluated Mr. Grimes’ performance during 2014. Based on this review, Mr. Johnson and Mr. Pardee determined that Mr. Grimes' award should be paid as achieved.

Mr. Johnson, Mr. Pardee, and Mr. Grimes, TVA's Executive Vice President and Chief Nuclear Officer (to whom Mr. Skaggs reported), subjectively evaluated Mr. Skaggs’ performance during 2014. Based on this review, Mr. Johnson, Mr. Pardee, and Mr. Grimes determined that Mr. Skaggs' award should be paid as achieved.

As a result of the above process, the Named Executive Officers were awarded the following EAIP payouts for 2014 in comparison to the 2014 target payouts:

2014 EAIP Payouts
Named Executive Officers	Salary	Target EAIP Incentive Opportunity (% of Salary)	Target EAIP Payout	Percent of Opportunity Achieved (As Adjusted)	Corporate Multiplier	Individual Performance Adjustment	Actual EAIP Payment
William D. Johnson	$950,000	100%	$950,000	123.00%	1.00	0%	$1,168,500
Charles G. Pardee	$620,000	80%	$496,000	120.75%	1.00	0%	$598,920
John M. Thomas, III	$550,000	80%	$440,000	123.00%	1.00	0%	$541,200
Joseph P. Grimes, Jr.	$535,000	80%	$428,000	120.75%	1.00	0%	$516,810
Michael D. Skaggs	$431,600	70%	$302,120	118.00%	1.00	0%	$356,502

Awards to the Named Executive Officers under the EAIP for 2014 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 ELTIP. Executives in critical positions make decisions that significantly influence the development and execution of TVA's long-term strategic objectives. The ELTIP is 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;

• Targeting award opportunities for each performance cycle at levels that approximate median levels of competitiveness with TVA's peer group and incorporating the Committee's policy that (i) about 80 percent of each executive's total long-term incentive opportunity be performance-based (under the ELTIP) and (ii) about 20 - 30 percent of each executive's total long-term incentive opportunity be retention and security-oriented under the Long-Term Deferred Compensation Plan ("LTDCP") as described below under the heading “Long-Term Deferred Compensation” or under the Long-Term Retention Incentive Plan ("LTRIP") as described below under the heading "Long-Term Retention Incentive Plan"; and

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

Under the ELTIP, an executive's incentive payment is calculated as follows:

ELTIP Payout = Salary X Target ELTIP Incentive Opportunity X Percent of Opportunity Achieved

The ELTIP establishes incentive opportunities for each of the Named Executive Officers that equal about 70 - 80 percent of each Named Executive Officer's total long-term compensation, based on a percentage of the base salary rate at the end of the performance cycle.  

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Named Executive Officers	Target Long-Term Incentive Opportunity*
Mr. Johnson	150%
Mr. Pardee	125%
Mr. Thomas	120%
Mr. Grimes	110%
Mr. Skaggs	90%
* Represents a percent of each Named Executive Officer’s salary.

The long-term incentive opportunities for the 2012-2014 performance cycle were approved by the TVA Board for Mr. Johnson and by Mr. Johnson, as CEO, for Mr. Pardee, Mr. Thomas, Mr. Grimes, and Mr. Skaggs. In February 2014, Mr. Johnson evaluated the compensation of Mr. Pardee, Mr. Thomas, Mr. Grimes, and Mr. Skaggs relative to TVA's peer group and TVA's compensation philosophy to determine whether to make adjustments to their compensation for 2014. For each of the Named Executive Officers, the objective of having target ELTIP awards constitute about 70 - 80 percent of total long-term compensation was achieved by maintaining the target ELTIP incentive opportunities for the 2012-2014 performance cycle at the same level as for the 2011-2013 performance cycle. In addition, these same target levels of long-term incentive opportunity kept the total direct compensation of each Named Executive Officer at the percentage of TVA's peer group described above. See Annual Incentive Compensation.

2012 - 2014 Performance Cycle

For the three-year cycle ended September 30, 2014, the TVA Board approved three overall long-term incentive measures of TVA performance to be applied to all participants in the ELTIP:

• Wholesale Rate Excluding Fuel;

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

• External Measures (including external nuclear performance indicators, stakeholder survey, media tone, and customer loyalty).

The Wholesale Rate Excluding Fuel performance measure represents 12-month averages comparing TVA's rates with those of surveyed regional holding company utilities, with goals that reflect percent gap improvements to achieve top-quartile rates by 2020. The goals approved for the wholesale rate excluding fuel performance measure for the three-year performance cycle ended September 30, 2014, were as follows:

• The threshold goal was TVA’s performance improvement to a 4.64 percent gap relative to the top-quartile of the ELTIP Rates Comparison Group's performance. The ELTIP Rates Comparison Group includes Ameren, American Electric Power, Dominion Resources, Duke Energy, PPL, Entergy, NextEra, and Southern Company.

• The target goal was TVA’s performance improvement to a 4.55 percent gap relative to the top-quartile of the ELTIP Rates Comparison Group's performance.

• The maximum goal was TVA's performance improvement to a 4.46 percent gap relative to the top-quartile of the ELTIP Rates Comparison Group's performance.

TVA obtained wholesale rate data (Electric Sales Revenue excluding Fuel/Electric Power Sales) for the ELTIP Rates Comparison Group from the U.S. Energy Information Administration’s EIA-826 Monthly Electric Utility Database.

The Load Not Served performance measure was calculated as a 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, 2014, with a threshold goal of 7.8 (99.999% reliability), a target goal of 4.4 (75th percentile), and a maximum goal of 3.1 (90th percentile).

The External Measures represent TVA's performance in areas including external nuclear performance indicators, stakeholder survey, media tone, and customer loyalty. The performance targets were based on incremental improvements leading to median performance in 2014 (threshold), mid second-quartile performance in 2014 (target), and top-quartile performance in 2014 (maximum).

The following table shows the performance goals and weighting and percent of opportunity achieved for the ELTIP for the three-year cycle ended September 30, 2014:

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ELTIP Performance Goals, Weighting, and Percent of Opportunity Achieved
	Goals				Performance Achievement
Performance Measure	Threshold (50%)	Target (100%)	Maximum (150%)	Performance Results	Actual (%)	X	Weight (%)	=	Result (%)
Wholesale Rate Excluding Fuel	4.64	4.55	4.46	4.62	61.5%		40%		24.6%
Load Not Served	7.8	4.4	3.1	4.2	107.7%		30%		32.3%
External Measures	76.9	84.8	92.0	86.90	114.6%		30%		34.4%
				Overall Percent of Opportunity Achieved					91.30	%
Recommended Payout Percent 100%

External measures are summarized below:

External Measures
Performance Measure	Weight	Results Achieved	Threshold	Target	Maximum
External performance indicators for the TVA nuclear fleet	25%	81.0	80.0	83.0	86.0
Percent of positive and balanced TVA news coverage compared to all TVA coverage	25%	93.0	80.0	84.0	85.0
Survey of public opinion of TVA	10%	81.0	81.0	81.5	82.0
Survey of TVA customers	10%	53.0	48.0	49.0	50.0
Board level significant events	30%	0	Two Unfavorable	Zero	Two Favorable
Composite score for external measures		86.9	76.9	84.8	92.0

As a part of the ELTIP, the TVA Board reserves discretion to review results and peer group comparisons and to approve adjustments in payouts, if appropriate.  The TVA Board adjusted the payout for 2014 based on the following information:

• Acknowledgment of overall good performance in 2014

• Wholesale rate unfavorability driven primarily by cold winter; essentially operational management performance was good

• Rewarding good financial discipline, as incremental revenue was used for debt reduction

As a result, the Named Executive Officers were awarded the following ELTIP payouts for the 2012 - 2014 performance cycle in comparison to the 2012 - 2014 performance cycle target payouts:

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2012 - 2014 Performance Cycle ELTIP Payouts
Named Executive Officers	Salary	Target ELTIP Incentive Opportunity	Target ELTIP Payout		Percent of Opportunity Achieved	ELTIP Payout
William D. Johnson	$950,000	150%	$1,425,000		100%	$1,425,000
Charles G. Pardee	$620,000	125%	$365,955	(1)	100%	$365,955	(1)
John M. Thomas, III	$550,000	120%	$660,000		100%	$660,000
Joseph P. Grimes, Jr.	$535,000	110%	$212,507	(2)	100%	$212,507	(2)
Michael D. Skaggs	$431,600	90%	$388,440		100%	$388,440

Notes

(1) Mr Pardee's award and target were prorated based on the number of months he was a participant in the plan. For the three-year performance cycle which ended September 30, 2014, Mr. Pardee participated 17 months.

(2) Mr. Grimes' award and target were prorated based on the number of months he was a participant in the plan. For the three-year performance cycle which ended September 30, 2014, Mr. Grimes participated 13 months.

Awards to the Named Executive Officers under the ELTIP for the performance cycle that ended September 30, 2014, are reported in the “Non-Equity Incentive Plan Compensation” column in the Summary Compensation Table.

2013 - 2015 Performance Cycle

The TVA Board approved the following overall measures of TVA performance for all participants in the ELTIP for the three-year cycle ending September 30, 2015:

Performance Measure	Weight	Threshold (50%)	Target (100%)	Maximum (150%)
Wholesale Rate Excluding Fuel(1)	40%	Target + 2%	2014 Business Plan (2014-2015 Rate)	Target - 2%
System Reliability Load Not Served(2)	30%	(99.999% reliability)	Top Quartile	Top Decile
Responsibility External Measures(3)	30%	77.9	85.8	92.9

Notes

(1)  The Wholesale Rate Excluding Fuel measure represents TVA's electric sales revenue excluding fuel divided by electric power sales. For the 2013-2015 ELTIP

performance cycle, the Wholesale Rate Excluding Fuel measure will be calculated using an average of the 2014 and 2015 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 events during

declared major storms). Value is expressed in system minutes and is the average of the three years within the ELTIP performance cycle.

(3)  For the 2013-2015 ELTIP performance cycle, the External Measures metric will be calculated using an average of the 2014 and 2015 results, except for the external performance indicators for the TVA nuclear fleet, which will be based only on 2015 results.

2014 - 2016 Performance Cycle

The TVA Board approved the following overall measures of TVA performance for all participants in the ELTIP for the three-year cycle ending September 30, 2016:

Performance Measure	Weight	Threshold (50%)	Target (100%)	Maximum (150%)
Wholesale Rate Excluding Fuel(1)	40%	Target + 2%	2014 Business Plan (2014-2016 Rate)	Target - 2%
System Reliability Load Not Served(2)	30%	(99.999% reliability)	Top Quartile	Top Decile
Responsibility External Measures(3)	30%	78.8	86.7	93.9

Notes

(1)  The Wholesale Rate Excluding Fuel measure represents TVA's electric sales revenue excluding fuel divided by electric power sales. For the 2014-2016 ELTIP performance cycle, the Wholesale Rate Excluding Fuel measure will be calculated using an average of the 2014, 2015, and 2016 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 events during declared major storms). Value is expressed in system minutes and is the average of the three years within the ELTIP performance cycle.

(3)  For the 2014-2016 ELTIP performance cycle, the External Measures metric will be calculated using an average of the 2014, 2015, and 2016 results, except for the external performance indicators for the TVA nuclear fleet, which will be based only on 2016 results.

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Long-Term Deferred Compensation. As a corporate agency of the United States, TVA does not have equity securities that provide stock awards, options, or other equity-based awards as compensation for its employees. To help retain leaders, TVA enters into agreements with certain executives, including the Named Executive Officers, which are administered under TVA's Long-Term Deferred Compensation Plan and provide a retention incentive similar to restricted stock or restricted stock units. The LTDCP agreements are aimed to encourage executives to remain with TVA and to provide, in combination with salary and EAIP and ELTIP incentive awards, a competitive level of total direct compensation. Under the LTDCP, credits are made to an account in an executive's name (typically on an annual basis) for a predetermined period. If the executive remains employed at TVA until the end of the period (typically three to five years), the executive becomes vested in the balance of the account, including any return on investment on the credits in the account, and receives a distribution in accordance with a deferral election made at the time the LTDCP agreement was made. The default return on investment on the credits in executives' accounts is interest calculated based on the composite rate of all marketable U.S. Treasury issues, which is credited daily to the balance reflected in the executives' accounts. Executives may alternatively choose to have their balances adjusted based on the return on certain mutual funds.

Annual LTDCP credits are awarded to the Named Executive Officers in amounts targeted to constitute about 20 - 30 percent of each Named Executive Officer's total long-term compensation. Annual credits provided to the Named Executive Officers under LTDCP agreements in 2014 are reported in the “All Other Compensation” column in the Summary Compensation Table. These credits are also reported in the “Registrant Contributions in Last FY” column in the Nonqualified Deferred Compensation Table, since the credits were placed in deferred compensation accounts in the Named Executives Officers' names.

Long-Term Retention Incentive Plan. In February 2014, Mr. Johnson approved the TVA Long-Term Retention Incentive Plan ("LTRIP"). Awards granted under the LTRIP are intended to provide retention incentives to participants similar to those provided by restricted stock or restricted units in publicly traded companies. Grants are awarded that vest after a specified period of time, usually no longer than three years.

These grants work in combination with the Executive Long-Term Incentive Plan and enable TVA to provide a targeted level of total long-term compensation that comprises both a variable, at-risk performance based component and a retention-based, time-vested component.

At this time, only one Named Executive Officer participates in the LTRIP, Mr. Grimes. Mr. Grimes was granted an award under the LTRIP on June 1, 2014. The award (a credit of $150,000) will vest on December 31, 2016. In the future, however, the LTRIP is expected to substantially replace the LTDCP as the primary mechanism for providing a retention-based, time-vested component of long-term compensation to executives.

Total Direct Compensation. Total direct compensation (salary, annual and long-term incentive. long-term retention, and long-term deferred compensation) is targeted at the median (50th percentile) level for similar positions at 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.

Considerations Specific to Mr. Johnson. At the beginning of 2014, the Committee, in consultation with its independent executive compensation consultant, Towers Watson, evaluated Mr. Johnson’s overall performance and then current compensation relative to TVA’s peer group to determine whether to recommend adjustments to Mr. Johnson’s compensation to the TVA Board for 2014. After a thorough review, including the consideration of chief executive officer median compensation data provided to the Committee by Towers Watson based on TVA’s peer group, the Committee recommended that the TVA Board approve the same compensation and incentive opportunities for Mr. Johnson for 2014 as for 2013. The 2014 compensation package for Mr. Johnson consisted of the following components: annual salary of $950,000, a target EAIP incentive opportunity of 100 percent of salary, a target ELTIP incentive opportunity of 150 percent of salary, a $300,000 credit under an LTDCP agreement, and an award of up to $325,000 under a performance arrangement (described in Other Agreements below).

The Committee made its recommendation based on the special place and mission of TVA and the belief that Mr. Johnson's compensation should be placed at greater risk than any other TVA executive (68 percent of overall target compensation).

 The chart below compares (i) the total direct compensation earned by Mr. Johnson for 2014; (ii) the 2014 compensation opportunity approved by the TVA Board for Mr. Johnson; and (iii) the chief executive officer median compensation data provided to the Committee by Towers Watson, based on TVA's peer group as discussed above.

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CEO Peer Group Compensation Comparison
Compensation Component	TVA CEO (Johnson)Compensation Earned for 2014				TVA CEO (Johnson)Compensation Opportunity for 2014				2014 Towers Watson Chief Executive Officer Median Market Data Range (TVA Peer Group)(1)
Base Salary	$950,000				$950,000				$1,140,000
Total Annual Incentive	123	%	(2	)	100	%	(2	)	105	%
					(target)				(target)
Total Cash Compensation	$2,118,500				$1,900,000				$2,337,000
Total Long-Term Incentive Compensation	150	%	(3)		150	%	(3)		415	%
					(target)				(target)
Total Direct Compensation	$4,168,500		(4)		$3,950,000		(4)		$7,068,000

Notes

(1) Market assessment effective October 2013.

(2) Mr. Johnson's target EAIP award for 2014 was 100 percent of $950,000, and his actual award was 123 percent of this amount.

(3) For the 2012-2014 ELTIP performance cycle, Mr. Johnson's target ELTIP award was 150 percent of $950,000, and his actual award was 100 percent of this amount.

(4) Includes an annual credit of $300,000 provided under a January 2013 LTDCP agreement and an award of up to $325,000 provided under an additional performance based arrangement. In 2014, Mr. Johnson received the maximum award of $325,000. See information regarding the details of the LTDCP agreement following the Grants of Plan-Based Awards Table.

Pension Benefits. All Named Executive Officers are eligible to participate in the following qualified plans available to all annual TVA employees:

•Defined benefit plan

- Original Benefit Structure ("OBS") for employees covered under the plan prior to January 1, 1996, with a pension based on a final average pay formula.

- Cash Balance Benefit Structure ("CBBS") for employees first hired on or after January 1, 1996, and prior to July 1, 2014, with a pension based on an account that receives pay credits equal to 6 percent of compensation plus interest.

•Employer Automatic Benefit Structure

- Employees who are first hired on or after July 1, 2014, or who are rehired on or after July 1, 2014, but who were previously not vested or who previously received their pension benefit in a lump-sum distribution, are participants in the Employer Automatic Benefit Structure ("EABS"). EABS members are eligible for a defined contribution retirement benefit in the 401(k) plan only and are not eligible to participate in the defined benefit plan.

•401(k) plan

- For OBS members, TVA provides matching contributions of 25 cents on every dollar up to 1.5 percent of eligible compensation.

- For CBBS members, TVA provides matching contributions of 75 cents on every dollar up to 4.5 percent of eligible compensation.

- For EABS members, TVA provides an automatic, non-elective contribution of 4.5 percent of eligible compensation and matching contributions of 75 cents on every dollar up to 4.5 percent of eligible compensation.

•Fixed and Variable Funds for OBS and CBBS members.

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.

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In addition to its qualified retirement plans, TVA has a Supplemental Executive Retirement Plan ("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.

Because “compensation” as calculated for purposes of the SERP benefit includes EAIP awards earned by the participants, the SERP benefits are somewhat sensitive to TVA's performance achievements. Also, discretionary actions by the TVA Board or the CEO to reduce EAIP payouts could reduce SERP benefits.

More information regarding these retirement and pension plans is found following the Pension Benefits Table.

Perquisites. In 2014, Mr. Skaggs received a lump sum payment in lieu of any relocation benefits he would have been eligible to receive under TVA's relocation policy. These payments are reported in the "All Other Compensation" column in the Summary Compensation Table.

TVA did not provide other perquisites to the Named Executive Officers in 2014.

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 Named Executive Officers 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.

Other Arrangements. Three NEOs have approved arrangements which provide opportunities for additional compensation.

• Mr. Johnson, upon appointment as CEO, has a TVA Board approved arrangement under which he would be eligible to receive an additional performance award of up to $325,000 per year based on the evaluation of his performance, which may be subjective and/or based on the achievement of defined short- and/or long-term goals. Under the arrangement, the TVA Board delegated to its Chair, in consultation with the Committee and with input from individual members of the TVA Board, the authority to set and approve any goals and the periods of performance for any such goals, evaluate the performance of Mr. Johnson subjectively and/or with respect to any goals, and approve any awards to Mr. Johnson.

The results of that review confirmed that Mr. Johnson delivered strong results in his second year as CEO:

- He demonstrated capability to establish a clear direction and lead TVA;

- Reduction in operations and maintenance costs throughout TVA in fiscal year 2014;

- Improved operational performance and reliability of TVA's nuclear fleet; and

- Best year ever for TVA's economic development efforts.

Based on these factors, the Chair approved an award to Mr. Johnson of $325,000 for 2014 under the performance arrangement.

• Mr. Skaggs operates under a CEO-approved arrangement that will provide Mr. Skaggs a performance award in the amount of $300,000 if the Watts Bar Nuclear Unit 2 project is completed on or ahead of schedule and on or under budget as defined by the “Watts Bar Unit 2 Project Completion Plan,” as long as Mr. Skaggs remains in a position responsible for completion of the project. The scheduled project completion date is December 31, 2015, under the “Watts Bar Unit 2 Project Completion Plan.”

• Mr. Pardee has a CEO-approved arrangement that provides additional awards of up to $200,000 per year based on the evaluation of performance that may be subjective and/or based on achievement of defined short-term and/or long-term goals. Under this arrangement, the President and CEO may set and approve goals and the periods of performance for such goals, evaluate performance subjectively and/or with respect to any goals, and approve any award. Based on these factors, the CEO approved an award to Mr. Pardee of $200,000 for 2014 under the performance incentive arrangement. Mr. Pardee was responsible for significant improvement of TVA's nuclear fleet and improving overall operational efficiency. For the first time since 2011, all three TVA

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nuclear plants are now operating under normal regulatory oversight levels. Mr. Pardee also ensured that TVA continued its top-decile safety performance, and Watts Bar Nuclear Unit 2 continues to be on schedule for completion within budget. Mr. Pardee was instrumental in driving the organizational restructuring which improved TVA's efficiency and operational effectiveness.

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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 2014 (and 2013 and 2012 as applicable).

Summary Compensation Table
Name and Principal Position	Year	Salary ($)		Bonus ($)	Stock Awards ($)	Option Awards ($)	Non-Equity Incentive Plan Compensation ($) (1)			Change in Pension Value and Nonqualified Deferred Compensation Earnings ($) (2)			All Other Compensation ($) (3)		Total ($)
William D. Johnson	2014	$	950,000	—	—	—	$	2,918,500		$	435,830		$	311,475	$	4,615,805
President and Chief	2013	$	712,500	—	—	—	$	2,992,386	(4)	$	2,063,395	(5)	$	461,250	$	6,229,531
Executive Officer	2012	$	—	—	—	—	$	—		$	—		$	—	$	—
Charles G. Pardee	2014	$	609,039	—	—	—	$	1,164,875		$	424,644		$	211,475	$	2,410,033
Executive Vice President	2013	$	—	—	—	—	$	—		$	—		$	—	$	—
and Chief Operating Officer	2012	$	—	—	—	—	$	—		$	—		$	—	$	—
John M. Thomas, III	2014	$	539,038	—	—	—	$	1,201,200		$	349,173		$	211,475	$	2,300,886
Executive Vice President	2013	$	522,000	—	—	—	$	1,285,648	(6)	$	161,119	(7)	$	172,500	$	2,141,267
and Chief Financial Officer	2012	$	520,000	—	—	—	$	997,277	(8)	$	493,749	(9)	$	203,349	$	2,214,375
Joseph P. Grimes, Jr.	2014	$	535,152	—	—	—	$	729,317		$	16,907		$	311,475	$	1,592,851
Executive Vice President	2013	$	—	—	—	—	$	—		$	—		$	—	$	—
and Chief Nuclear Officer	2012	$	—	—	—	—	$	—		$	—		$	—	$	—
Michael D. Skaggs	2014	$	425,535	—	—	—	$	744,942		$	732,916		$	186,475	$	2,089,868
Senior Vice President,	2013	$	416,596	—	—	—	$	785,703	(10)	$	212,967	(11)	$	197,500	$	1,612,766
Watts Bar Nuclear Operations and Construction	2012	$	—	—	—	—	$	—		$	—		$	—	$	—

Notes 

(1) The column includes the amounts below for 2014.

Non-Equity Incentive Plan Compensation
	William D. Johnson	Charles G. Pardee	John M. Thomas, III	Joseph P. Grimes, Jr.	Michael D. Skaggs
EAIP	$1,168,500	$598,920	$541,200	$516,810	$356,502
ELTIP	$1,425,000	$365,955	$660,000	$212,507	$388,440
PIA	$325,000	$200,000	$0	$0	$0
Total	$2,918,500	$1,164,875	$1,201,200	$729,317	$744,942

(2) This column includes the amounts listed below for 2014.

Change in Pension Value and Nonqualified Deferred Compensation Earnings
	William D. Johnson	Charles G. Pardee	John M. Thomas, III	Joseph P. Grimes, Jr.	Michael D. Skaggs
Increase under CBBS	$22,219	$18,979	$41,205	$16,907	$59,147
Increase under SERP	$413,611	$405,665	$307,968	$0	$673,769
Total	$435,830	$424,644	$349,173	$16,907	$732,916

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(3) This column includes the amonts listed below. The amounts listed were earned over the 12-month period ended on September 30, 2014.

All Other Compensation
	William D. Johnson	Charles G. Pardee	John M. Thomas, III	Joseph P. Grimes, Jr.	Michael D. Skaggs
LTDCP Credit	$300,000	$200,000	$200,000	$150,000	$150,000
LTRIP Credit	$0	$0	$0	$150,000	$0
401(k)	$11,475	$11,475	$11,475	$11,475	$11,475
Lump-Sum Payment in Lieu of Relocation	$0	$0	$0	$0	$25,000
Other	$0	$0	$0	$0	$0
Total	$311,475	$211,475	$211,475	$311,475	$186,475

(4) Represents $805,766 awarded under the EAIP, $1,861,620 awarded under the ELTIP, and $325,000 awarded under a performance incentive arrangement. Although this $325,000 was disclosed in Item 11, Executive Compensation -Compensation Discussion and Analysis - Considerations Specific to Mr. Johnson and -Other Agreements and in the Grant of Plan-Based Awards Table in TVA’s Annual Report on Form 10-K for the fiscal year ended September 30, 2013 (the “2013 Annual Report”), this amount was inadvertently not included in the Summary Compensation Table in the 2013 Annual Report. This amount was paid to Mr. Johnson in October 2014.

(5) Reflects increases of $12,066 under the CBBS and $2,051,329 under the SERP.

(6) Represents $470,454 awarded under the EAIP and $815,194 awarded under the ELTIP.

(7) Reflects a decrease of $16,374 under the CBBS and an increase of $177,493 under the SERP.

(8) Represents $468,000 awarded under the EAIP and $529,277 awarded under the ELTIP.

(9) Reflects increases of $58,777 under the CBBS and $434,972 under the SERP.

(10) Represents $297,763 awarded under the EAIP and $487,940 awarded under the ELTIP.

(11) Reflects a decrease of $18,824 under the CBBS and an increase of $231,791 under the SERP.

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The following table provides information on non-equity incentive plan awards and the possible range of payouts associated with incentives the Named Executive Officers were eligible to receive in the performance cycle ended in 2014.

Grants of Plan-Based Awards Table
		Estimated Possible Payouts Under Non-Equity Incentive Plan Awards (1)
Name	Plan	Threshold (2) ($)	Target (2) ($)	Maximum (2) ($)
William D. Johnson	EAIP(3)	$475,000	$950,000	$1,425,000
	ELTIP(4)	$712,500	$1,425,000	$2,137,500
	PIA(7)	$0	$0	$325,000
Charles G. Pardee	EAIP(3)	$248,000	$496,000	$744,000
	ELTIP(4),(5)	$182,978	$365,955	$548,933
	PIA(8)	$0	$0	$200,000
John M. Thomas, III	EAIP(3)	$220,000	$440,000	$660,000
	ELTIP(4)	$330,000	$660,000	$990,000
Joseph P. Grimes, Jr.	EAIP(3)	$214,000	$428,000	$642,000
	ELTIP(4), (6)	$106,254	$212,507	$318,761
Michael D. Skaggs	EAIP(3)	$151,060	$302,120	$453,180
	ELTIP(4)	$194,220	$388,440	$582,660

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 an NEO based on 2014 performance.

(3)  Target incentive opportunities as a percentage of salaries were as follows:  Mr. Johnson, 100 percent; Mr. Pardee 80 percent; Mr. Thomas, 80 percent; Mr. Grimes, 80 percent; and Mr. Skaggs, 70 percent.   Actual EAIP awards earned for performance in 2014 are reported for each of the Named Executive Officers under “Non-Equity Incentive Plan Compensation” in the Summary Compensation Table.  See Compensation Discussion and Analysis for a discussion of how each award was determined.

(4) Target incentive opportunities for the three-year performance cycle ended September 30, 2014, as a percentage of salaries were as follows: Mr. Johnson, 150 percent; Mr. Pardee 125 percent; Mr. Thomas, 120 percent; Mr. Grimes, 110 percent; and Mr. Skaggs, 90 percent.  ELTIP performance measures for the three-year cycle ended September 30, 2014, were Wholesale Rate Excluding Fuel, Load Not Served, and External Measures.  Actual ELTIP awards earned for the performance cycle ended on September 30, 2014, are reported for each of the Named Executive Officers under “Non-Equity Incentive Plan Compensation” in the Summary Compensation Table.  See Compensation Discussion and Analysis for a discussion of how each award was determined.

(5) Mr. Pardee's estimated possible payout under the ELTIP for the performance period ended September 30, 2014, is prorated based on the number of months he was a participant in the performance cycle (17). Accordingly, his possible payouts under the ELTIP are $182,978 for threshold ($387,500 X 17/36), $365,955 for target ($775,000 x 17/36), and $548,933 for maximum ($1,162,500 x 17/36).

(6) Mr. Grimes' estimated possible payout under the ELTIP for the performance period ended September 30, 2014, is prorated based on the number of months he was a participant in the performance cycle (13). Accordingly, his possible payouts under the ELTIP are $106,254 for threshold ($294,250 x 13/36), $212,507 for target ($588,500 x 13/36), and $318,761 for maximum ($822,750 x 13/36).

(7) Reflects the maximum award amount Mr. Johnson was eligible to receive under a performance incentive arrangement described in Compensation Discussion and Analysis- Executive Compensation Program Components - Other Agreements. The actual award to be paid to Mr. Johnson is reported under "Non-Equity Incentive Plan Compensation" in the Summary Compensation Table.

(8) Reflects the maximum award amount Mr. Pardee was eligible to receive under a performance incentive arrangement described in Compensation Discussion and Analysis- Executive Compensation Program Components - Other Agreements. The actual award to be paid to Mr. Pardee is reported under "Non-Equity Incentive Plan Compensation" in the Summary Compensation Table.

Awards under the EAIP, ELTIP, and PIA will be paid in cash during the first quarter of 2015.

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Long-Term Deferred Compensation Plan

The TVA Long-Term Deferred Compensation Plan offers incentives to executives to encourage them to stay with TVA and to provide competitive levels of total direct compensation to such executives.  Participating executives enter agreements in which deferred compensation credits are made to an account in the participant's name.  Credits are made on an annual basis for an established period of time.  Interest is credited daily to the balance reflected in the participant's deferral account.  Interest is calculated based on the composite rate of all marketable U.S. Treasury issues.  Alternatively, participants may choose to have their balance adjusted based on the return on certain mutual funds.  Credits vest after a period fixed in the agreement, and distribution is based on the election made at the time the agreement is entered. A summary of the LTDCP agreements, some of which are reflected in the Summary Compensation Table for the Named Executive Officers, is listed below. The date and amount of each credit, as well as the vesting of each award, is outlined in the table.  See also the Nonqualified Deferred Compensation Table below, which also includes information with respect to amounts credited under these and prior LTDCP agreements.

Long-Term Deferred Compensation
	2011	2012	2013	2014	2015	2016
Mr. Johnson			01/01/2013 credit of $300,000. Vested 09/30/2013.(1)	10/01/2013 credit of $300,000. Vested 09/30/2014.(1)	10/01/2014 credit of $300,000. Vests 09/30/2015.(1)
Mr. Pardee			05/01/2013 credit of $200,000. Vests 12/31/2016.(2)	01/01/2014 credit of $200,000. Vests 12/31/2016.(2)	01/01/2015 credit of $200,000. Vests 12/31/2016.(2)	01/01/2016 credit of $200,000. Vests 12/31/2016.(2)
Mr. Thomas	10/01/2010 credit of $50,000. Vested 09/30/2013.(3)	10/01/2011 credit of $100,000. Vested 09/30/2013.(3) 01/01/2012 credit of $50,000. Vested 12/31/2012.(3)	10/01/2012 credit of $100,000. Vested 09/30/2013.(3) 05/01/2013 credit of $50,000. Vested 04/30/2014.(3)	03/01/2014 credit of $200,000. Vests 12/31/2014.(3)
Mr. Grimes			09/01/2013 credit of $250,000. Vests 12/31/2015.(4)	01/01/2014 credit of $150,000. Vests 12/31/2015.(4)	01/01/2015 credit of $150,000. Vests 12/31/2015.(4)
Mr. Skaggs			10/01/2012 credit of $100,000. Vested 09/30/2014.(5) 03/01/2013 credit of $50,000. Vests 12/31/2016.(6)	10/01/2013 credit of $100,000. Vested 09/30/2014.(5) 01/01/2014 credit of $50,000. Vests 12/31/2016.(6)	01/01/2015 credit of $150,000. Vests 12/31/2016.(6)	01/01/2016 credit of $150,000. Vests 12/31/2016.(6)

Notes

(1) Each credit, and earnings on such credit, were or will be distributed to Mr. Johnson in a lump sum at the time of vesting. In the event TVA terminates Mr. Johnson's employment during the term of the LTDCP agreement through no act or delinquency of his own, the agreement will be terminated as of the date of termination, no further credits will be made under it, and any credits in his account from this agreement including earnings on such credit will become vested. If Mr. Johnson voluntarily terminates his employment or TVA terminates Mr. Johnson's employment for cause prior to the expiration of the agreement, then any unvested credit, and earnings on such credit, in Mr. Johnson's account will be forfeited.

(2) Mr. Pardee will vest in these credits only if he remains employed by TVA until the expiration of the LTDCP agreement on December 31, 2016. All vested credits, and earnings on such credits, will be distributed to him in five annual installments following his separation from service with TVA. In the event TVA terminates Mr. Pardee’s employment during the term of a LTDCP agreement through no act or delinquency of his own, any credits under the agreement and earnings on such credits in Mr. Pardee’s account at the time of termination will become vested and distributed to him in five annual installments. If Mr. Pardee voluntarily terminates his employment or TVA terminates Mr. Pardee's employment for cause prior to the expiration of the applicable agreement, then all credits under that agreement, and earnings on such credits, in Mr. Pardee’s account may be forfeited.

(3)  Mr. Thomas has elected for all credits and earnings on credits to be paid out in a lump-sum upon vesting.

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(4)  Mr. Grimes will vest in these credits only if he remains employed by TVA until the expiration of the LTDCP agreement on December 31, 2015. All vested credits, and earnings on such credits, will be distributed to him in a lump sum following his separation from service with TVA. In the event TVA terminates Mr. Grimes’ employment during the term of a LTDCP agreement through no act or delinquency of his own, any credits under the agreement and earnings on such credits in Mr. Grimes’ account at the time of termination will become vested and distributed to him in a lump-sum. If Mr. Grimes voluntarily terminates his employment or TVA terminates Mr. Grimes’ employment for cause prior to the expiration of the applicable agreement, then all credits under that agreement, and earnings on such credits, in Mr. Grimes’ account may be forfeited.

(5) Mr. Skaggs vested in these credits on September 30, 2014. Credits, and earnings on such credits, will be distributed to Mr. Skaggs in ten annual installments upon separation of service.

(6) Mr. Skaggs will vest in these credits only if he remains employed by TVA until the expiration of the LTDCP agreement on December 31, 2016. All vested credits, and earnings on such credits, will be distributed to him in ten annual installments following his separation from service with TVA. In the event TVA terminates Mr. Skaggs' employment during the term of a LTDCP agreement through no act or delinquency of his own, any credits under the agreement and earnings on such credits in Mr. Skaggs' account at the time of termination will become vested and distributed to him in ten annual installments. If Mr. Skaggs voluntarily terminates his employment or TVA terminates Mr. Skaggs' employment for cause prior to the expiration of the applicable agreement, then all credits under that agreement, and earnings on such credits, in Mr. Skaggs' account may be forfeited.

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, 2014, 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 20.

Pension Benefits Table
Name	Plan Name	Number of Years of Credited Service(1) (#)		Present Value of Accumulated Benefit ($)	Payments During Last Year ($)
William D. Johnson	(1) Qualified Plan – CBBS	1.750	(2)	$34,285	$0
	(2) Non-Qualified – SERP Tier 1	6.750	(2)	$2,464,940	$0
Charles G. Pardee	(1) Qualified Plan – CBBS	1.417	(3)	$35,420	$0
	(2) Non-Qualified – SERP Tier 1	6.417	(3)	$1,043,387	$0
John M. Thomas, III	(1) Qualified Plan – CBBS	8.833		$210,342	$0
	(2) Non-Qualified – SERP Tier 1	8.833		$1,374,226	$0
Joseph P. Grimes, Jr.	(1) Qualified Plan – CBBS	1.083		$20,182	$0
	(2) Non-Qualified – SERP Tier 1	1.083		$0	$0
Michael D. Skaggs	(1) Qualified Plan – CBBS	20.583		$452,477	$0
	(2) Non-Qualified – SERP Tier 1	20.583		$2,545,977	$0

Notes

(1) Limited to 24 years when determining supplemental benefits available under SERP Tier 1, described below.

(2) Mr. Johnson has been granted five additional years of credited service for pre-TVA employment, and the offset for prior employer pension benefits associated with the additional five years of credited service has been 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 CBBS taking into account the additional years of credited service being used for SERP benefit calculation purposes. As of September 30, 2014, the present value of this benefit was $2,464,940. Without the additional years of credited service, the present value of Mr. Johnson's accumulated benefit would be $437,232.

(3) Mr. Pardee has been granted five additional years of credited service for pre-TVA employment, and the offset for prior employer pension benefits associated with the additional five years of credited service has been 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 CBBS taking into account the additional years of credited service being used for SERP benefit calculation purposes. As of September 30, 2014, the present value of this benefit was $1,043,387. Without the additional years of credited service, the present value of Mr. Pardee's accumulated benefit would be $72,853.

Qualified Retirement Plans.  TVA sponsors a qualified defined benefit plan and a qualified defined contribution 401(k) plan which are administered by the Tennessee Valley Authority Retirement System ("TVARS").  The retirement benefits have three structures -- the OBS, the CBBS, and the EABS.  Participation in the OBS is limited to employees who were hired prior to January 1, 1996.  All employees first hired by TVA on or after January 1, 1996, and prior to July 1, 2014, participate in the CBBS.  All employees first hired by TVA on or after July 1, 2014, or rehired by TVA on or after July 1, 2014, but who were previously not vested or who previously received their pension benefit in a lump-sum distribution, participate in the EABS, which provides for a defined contribution retirement benefit in the 401(k) plan only. TVARS rules and IRS regulations set limits on employee and employer contributions and compensation that can be counted in benefit calculations.

CBBS. All Named Executive Officers are members of the CBBS, under which each member has a cash balance account that receives pay credits equal to six percent of compensation each pay period (every two weeks).  For executives who are members of the CBBS, 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 compensation in 2014 could not exceed $255,000 pursuant to the IRS annual compensation limit applicable to qualified plans.  The account is credited with interest each month, and interest is compounded on an annual basis.  The annual interest rate used for interest credits is determined each January 1.  The interest rate is three percent greater than the percentage increase in the 12-month average of the Consumer Price Index for the period ended on the previous October 31.  The minimum interest rate is six percent and the maximum interest rate is 10 percent unless the TVARS Board of Directors, with TVA's approval, selects a higher interest rate.  When a member elects to

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begin receiving retirement benefits, the cash balance account is converted to a monthly pension payment by dividing the ending value of the cash balance account by a conversion factor set forth in the plan based on the member's actual age in years and months.

Members with at least five years of CBBS service are eligible to receive an immediate benefit.  CBBS service is the length of time spent as a member of the TVA Retirement System and does not include credit for unused sick leave, forfeited annual leave, or pre-TVA employment military service.  The CBBS does not provide for early retirement benefits to any Named Executive Officer or any other member in the CBBS.

OBS. None of the Named Executive Officers is a member of the OBS.

EABS. None of the Named Executive Officers is a member of the EABS.

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 a limited number of executives, including the Named Executive Officers.  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 IRS 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 ten.  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 ten 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 TVA's long-term disability plan), 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.  All of the Named Executive Officers are participants in 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 defined benefit plan, and prior employer pension benefits when applicable.

The TVA Sponsored 401(k) Plan.  Members of the TVA Retirement System, including the Named Executive Officers, may elect to participate in the TVA Retirement System's 401(k) plan on a before-tax, after-tax and/or Roth basis.  For OBS members, TVA provides a matching contribution of $0.25 on every dollar contributed on a before-tax, after-tax, and/or Roth basis, up to 1.5 percent of the participant's annual salary. For CBBS members, TVA provides a matching contribution of $0.75 on every dollar contributed on a before-tax, after-tax, and/or Roth basis, up to 4.5 percent of the participant's annual salary. For EABS members, TVA provides an automatic, non-elective contribution of 4.5 percent of eligible compensation and matching contributions of 75 cents on every dollar up to 4.5 percent of eligible compensation. Any eligible member must have three years of TVA service to be vested in matching contributions and any employer automatic contributions from TVA.

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Nonqualified Deferred Compensation

The following table provides information regarding deferred contributions, earnings, and balances for each of the Named Executive Officers.  The amounts reported under this table do not represent compensation in addition to the compensation that was earned in 2014 and already reported in the Summary Compensation Table, but rather the amounts of compensation earned by the Named Executive Officers in 2014 or prior years that were or have been deferred.

Nonqualified Deferred Compensation Table
Name	Executive Contributions in 2014 ($)	Registrant Contributions in 2014 ($)	Aggregate Earnings in 2014(1) ($)	Aggregate Withdrawals/ Distributions ($)	Aggregate Balance at September 30 2014(2) ($)
William D. Johnson	$0	$300,000	$6,044	$304,660	$306,027
Charles G. Pardee	$0	$200,000	$6,719	$0	$408,407
John M. Thomas, III	$0	$200,000	$2,921	$310,857	$202,382
Joseph P. Grimes, Jr.	$0	$150,000	$7,319	$0	$407,478
Michael D. Skaggs	$0	$150,000	$204,997	$0	$3,605,365

Notes

(1) Includes vested and unvested earnings. Because none of the amounts is above market earnings under SEC rules, none of these amounts is included in the Summary Compensation Table.

(2)  Includes vested and unvested contributions and earnings.

TVA normally allows participants in the EAIP, ELTIP, and LTDCP to defer all or a portion of the compensation earned under those plans and eligible for deferral under 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 of several notional 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, funds are distributed pursuant to elections made in accordance with applicable IRS regulations.

Participants in the EAIP and ELTIP, including the Named Executive Officers, were not allowed to elect to defer any portion of their awards received under the plans for 2014.

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Potential Payments on Account of Retirement/Resignation, Termination without Cause, Termination with Cause, or Death/Disability

The tables below show certain potential payments that would have been made to each Named Executive Officer if his employment had been terminated on September 30, 2014, 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.

William D. Johnson	Retirement/Resignation			Termination without Cause			Termination with Cause		Death/ Disability
Severance Agreement(1)	$	—		$	1,900,000		$	—	$	—
LTDCP	$	306,027		$	306,027		$	306,027	$	306,027
SERP	$	—	(2)	$	—	(2)	$	—	$	2,464,940	(3)
Deferred Compensation	$	—		$	—		$	—	$	—
Total Value of Potential Payments	$	306,027		$	2,206,027		$	306,027	$	2,770,967
Notes (1)  In October 2012, TVA entered into an arrangement with Mr. Johnson 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. Johnson 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. Johnson voluntarily terminates his employment or voluntarily retires, or his employment is terminated “for cause” as defined in the agreement. (2)  The five-year vesting requirement has not been met. (3)  Represents the present value of the accumulated benefit.  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.

Charles G. Pardee	Retirement/Resignation			Termination without Cause			Termination with Cause		Death/ Disability
Severance Agreement(1)	$	—		$	—		$	—	$	—
LTDCP	$	—		$	408,407		$	—	$	408,407
SERP	$	—	(2)	$	—	(2)	$	—	$	1,043,387	(3)
Deferred Compensation	$	—		$	—		$	—	$	—
Total Value of Potential Payments	$	—		$	408,407		$	—	$	1,451,794
Notes (1)  Mr. Pardee 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.  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.

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John M. Thomas, III	Retirement/Resignation			Termination without Cause			Termination with Cause		Death/ Disability
Severance Agreement(1)	$	—		$	—		$	—	$	—
LTDCP	$	—		$	202,382		$	—	$	202,382
SERP	$	1,374,226	(2)	$	1,374,226	(2)	$	—	$	1,374,226	(3)
Deferred Compensation	$	—		$	—		$	—	$	—
Total Value of Potential Payments	$	1,374,226		$	1,576,608		$	—	$	1,576,608
Notes (1)  Mr. Thomas does not have a severance agreement with TVA. (2)  Represents the present value of the accumulated benefit. Actual benefit would be paid in five annual installments beginning at age 55. (3)  Represents the present value of the accumulated benefit.  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.

Joseph P. Grimes, Jr.	Retirement/Resignation			Termination without Cause			Termination with Cause		Death/ Disability
Severance Agreement(1)	$	—		$	535,000		$	—	$	—
LTDCP	$	—		$	407,478		$	—	$	407,478
SERP	$	—	(2)	$	—	(2)	$	—	$	—	(2)
Deferred Compensation(4)	$	—		$	—		$	—	$	—
Total Value of Potential Payments	$	—		$	942,478		$	—	$	407,478
Notes (1)  In June, 2013, TVA entered into an arrangement with Mr. Grimes that provides a lump-sum payment equal to one year's annual salary in the event TVA terminates Mr. Grimes' employment without cause. (2)  The five-year vesting requirement has not been met.

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Michael D. Skaggs	Retirement/Resignation			Termination without Cause			Termination with Cause		Death/ Disability
Severance Agreement(1)	$	—		$	—		$	—	$	—
LTDCP	$	—		$	735,284		$	—	$	735,284
SERP	$	2,545,977	(2)	$	2,545,977	(2)	$	—	$	2,545,977	(3)
Deferred Compensation(4)	$	2,870,082		$	2,870,082		$	2,870,082	$	2,870,082
Total Value of Potential Payments	$	5,416,059		$	6,151,343		$	2,870,082	$	6,151,343
Notes (1)  Mr. Skaggs does not have a severance agreement with TVA. (2)  Represents the present value of the accumulated benefit. Actual benefit would be paid in ten annual installments upon separation from service. (3)  Represents the present value of the accumulated benefit.  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. (4)  Amounts that Mr. Skaggs earned in past years but elected to defer, which are payable pursuant to elections he made and applicable IRS rules.

Other Agreements

Except as described above and in the Compensation Discussion and Analysis, there are no other agreements between TVA and any of the Named Executive Officers.

Director Compensation

The TVA Act provides for up to nine directors on the TVA Board.  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 United States Government.  As discussed under Compensation Discussion and Analysis — Executive Compensation Program Components — Federal Salary Freeze, pursuant to federal legislation, a three-year freeze on these statutory pay adjustments to TVA director stipends applied to calendar years 2011, 2012, and 2013. In 2014, the stipend for TVA directors was increased to $49,400 per year unless (1) the director chairs a TVA Board committee, in which case the stipend was increased to $50,500 per year; or (2) the director is the Chair of the TVA Board, in which case the stipend was increased to $55,000 per year.  Directors are also reimbursed under federal law for travel, lodging, and related expenses while attending meetings and for other official TVA business.

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The annual stipends provided by the TVA Act for each director and for the Chair of the TVA Board as of November 14, 2014, are listed below:

TVA Board Annual Stipends
Name	Annual Stipend ($)
Marilyn A. Brown	$49,400
V. Lynn Evans	$50,500
Barbara S. Haskew	$50,500
Richard C. Howorth	$50,500
C. Peter Mahurin	$50,500
Michael R. McWherter	$49,400
Joe H. Ritch	$55,000
William B. Sansom	$50,500

The following table provides information on the compensation received by TVA’s directors during 2014

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) ($)	All Other Compensation ($)	Total ($)
Marilyn A. Brown	$49,246	—	—	—	—	$549	$49,795
V. Lynn Evans	$50,186	—	—	—	—	$2,792	$52,978
Barbara S. Haskew(2)	$50,346	—	—	—	—	$2,305	$52,651
Richard C. Howorth	$50,524	—	—	—	—	$2,885	$53,409
C. Peter Mahurin	$50,524	—	—	—	—	$562	$51,086
Michael R. McWherter	$49,246	—	—	—	—	$549	$49,795
Joe H. Ritch	$52,081	—	—	—	—	$2,989	$55,070
William B. Sansom(2)	$53,289	—	—	—	—	$2,427	$55,716

Notes

(1)  TVA directors do not participate in the TVA Retirement System, TVA's SERP, or any non-qualified deferred compensation plan available to TVA employees. However, as appointed officers of the United States 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) Mr. Sansom and Ms. Haskew's terms expired in May 2014, but they are entitled to remain in office until the earlier of the end of the current session of Congress or the date a successor takes office.

The directors are not eligible to participate in any incentive programs available to TVA employees.  The directors do not participate in the TVA Retirement System and do not participate in TVA's SERP.  However, as appointed officers of the United States 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 small 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).

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Directors may also retire with an immediate benefit under FERS if they reach their minimum retirement age based on type of retirement and years of service and have accumulated at least 10 years of FERS creditable service.  For directors who reach the minimum retirement age and have at least 10 years of FERS creditable service, the annuity will be reduced by five percent for each year the director is under age 62.

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 IRS 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.

Compensation Committee Interlocks and Insider Participation

The People and Performance Committee of the TVA Board currently consists of the following three directors: Barbara S. Haskew, Chair, V. Lynn Evans, and C. Peter Mahurin.

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

Barbara S. Haskew, Chair

V. Lynn Evans

C. Peter Mahurin

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 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 official 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

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are (1) financial interests which have been deemed by the 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 United States.

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 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 Standard Programs and Processes 11.8.1, Business Ethics, which requires employees, including TVA’s directors and executive officers, to comply with the guidelines outlined in the Standards of Ethical Conduct and which restates 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, which provides as follows:

In addition to the law and policy applicable to all TVA employees, TVA Directors and the CEO shall comply with the following additional policy restricting the holding of certain financial interests:

1. For purposes of this policy, “financial interest” means an interest of a person, or of a person’s spouse or minor child, arising by virtue of investment or credit relationship, ownership, employment, consultancy, or fiduciary relationship such as director, trustee, or partner. However, financial interest does not include an interest in TVA or any interest:

•comprised solely of a right to payment of retirement benefits resulting from former employment or fiduciary relationship,

•arising solely by virtue of cooperative membership or similar interest as a consumer in a distributor of TVA power, or

•arising by virtue of ownership of publicly traded securities:

▪ of any single entity with a value of $25,000 or less, or

▪ of a parent entity with one or more subsidiaries covered by this Policy that collectively contribute to a proportionate owned value of the parent’s securities in an amount of $25,000 or less, or

▪ of a diversified mutual fund with a value of any amount, or

▪ of a sector mutual fund, exchange traded fund, or similar investment fund with a value of any amount, provided the fund is not primarily focused on the wholesale or retail generation, transmission, or sale of electricity in North America).

2. Directors and the CEO shall not hold a financial interest in any distributor of TVA power.

3. Directors and the CEO shall not hold a financial interest in 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.

4. Directors and the CEO shall not hold a financial interest in 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.

5. Any action taken or interest held that creates, or may reasonably be perceived as creating, a conflicting financial interest restricted by this additional policy applicable to TVA Directors and the CEO shall immediately be disclosed to the Chair of the Board of Directors and the Chair of the committee exercising the function of the audit committee of the Board. Subject to any commitment made in connection with appointment to office or other requirement of law, a newly appointed Director or CEO shall proceed promptly with arrangements to divest the conflicting financial interest but should in any event conclude such divestiture within one year from the date of assuming office. The audit committee shall be responsible for initially reviewing all other such disclosures and making recommendations to the entire Board on what action, if any, should be taken. The entire Board, without the vote of any Director(s) involved, shall determine the appropriate action to be taken. No such review, recommendation, or determination is required, however, where an

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inadvertent violation is promptly remedied upon discovery and reported to the Chair of the Board of Directors and the Chair of the audit committee as provided herein.

6. Any waiver of this additional policy applicable to TVA Directors and the CEO may be made only by the 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 or a member of the TVA Board should do if a person covered by the Protocol asks for assistance in obtaining something 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 DOE.  See Item 1, Business and Note 22.

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, 2014. This credit facility matures on September 30, 2015 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 — 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 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. TVA will indefinitely continue to make payments to the U.S. Treasury as a return on the remaining $258 million of the Power Program Appropriation Investment.  See Note 17 — Appropriation Investment.

ITEM 14.  PRINCIPAL ACCOUNTANT FEES AND SERVICES

The following table shows the fees of Ernst & Young LLP for the audit and audit-related services for the years ended September 30, 2014 and 2013.

Principal Accountant Fees and Services (in actual dollars)
Year	Principal Accountant	Audit Fees(1)		Audit-Related Fees		All Other Fees	Total
2014	Ernst & Young LLP	$	2,678,461	$	—	—	$	2,678,461
2013	Ernst & Young LLP	$	2,492,101	$	—	—	$	2,492,101

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; audit of TVA's federal closing package for the preparation and audit of the 2013 and 2014 federal consolidated financial statements of which TVA is a component; and Bond offering and other financing comfort letters.

The TVA Board has an Audit, Risk, and Regulation Committee.  Under the TVA Act, the Audit, Risk, and Regulation Committee, in consultation with the Inspector General, recommends to the TVA Board the selection of an external auditor.  TVA’s Audit, Risk, and Regulation Committee, in consultation with the Inspector General, recommended that the TVA Board select Ernst & Young LLP as TVA’s external auditor for the 2013 and 2014 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 be pre-approved by the Audit, Risk, and Regulation Committee. The Policy also lists the following services as ones the external auditor is not permitted to perform. The prohibited non-audit services are:

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

• Financial information system design and implementation;

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• 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, Risk, and Regulation 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, Risk, and Regulation Committee’s next meeting.

The Audit, Risk, and Regulation Committee pre-approved all audit services for 2013 and 2014.

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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 Flow

Consolidated Statements of Changes in Proprietary Capital

Notes to Consolidated Financial Statements

Report of Independent Registered Public Accounting Firm (Ernst and 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.

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(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, 2007, 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
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	$1,000,000,000 Spring Maturity Credit Agreement Dated as of June 25, 2012, among TVA, The Bank of New York Mellon as Administrative Agent, Letter of Credit Issuer, and a Lender, Bank of America, N.A., Canadian Imperial Bank of Commerce, New York Agency, First Tennessee Bank National Association, Morgan Stanley Bank, N.A., and Toronto Dominion (New York) LLC (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on June 28, 2012, File No. 000-52313)
10.2	Amendment Dated as of December 12, 2012, to $1,000,000,000 Spring Maturity Credit Agreement Dated as of June 25, 2012, among TVA, The Bank of New York Mellon as Administrative Agent, Letter of Credit Issuer, and a Lender, Bank of America, N.A., Canadian Imperial Bank of Commerce, New York Agency, First Tennessee Bank National Association, Morgan Stanley Bank, N.A., and Toronto Dominion (New York) LLC (Incorporated by reference to Exhibit 10.2 to TVA's Current Report on Form 8-K filed on December 17, 2012, File No. 000-52313)
10.3	$1,000,000,000 Winter Maturity Credit Agreement Dated as of December 13, 2012, Among TVA, Royal Bank of Canada, as Administrative Agent, Letter of Credit Issuer, and a Lender, The Royal Bank of Scotland plc, UBS AG, Stamford Branch, Mizuho Corporate Bank, Ltd., Wells Fargo Bank, National Association, The Bank of Nova Scotia, and PNC Bank, National Association (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on December 17, 2012, File No. 000-52313)
10.4	Assignment and Assumption Agreement Dated as of April 30, 2014, Between UBS AG, Stamford Branch, and Sumitomo Mitsui Banking Corporation Relating to $1,000,000,000 Winter Maturity Credit Agreement Dated as of December 13, 2012 (Incorporated by reference to Exhibit 10.2 to TVA’s Quarterly Report on Form 10-Q for the quarter March 31, 2014, File No. 000-52313)
10.5	$500,000,000 April 2018 Maturity Credit Agreement Dated as of April 5, 2013, 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 April 10, 2013, File No. 000-52313)
10.6	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)
10.7	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)
10.8	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 March 31, 2014, File No. 000-52313)
10.9	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)

187

10.10	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)
10.11	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)
10.12	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)
10.13	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)
10.14	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)
10.15	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)
10.16*	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)
10.17*	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)
10.18*	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)
10.19	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)
10.20	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)
10.21	Construction Management Agreement Dated as of January 17, 2012, Between John Sevier Combined Cycle Generation LLC and TVA (Incorporated by reference to Exhibit 10.3 to TVA's Quarterly Report on Form 10-Q for the quarter ended December 31, 2011, File No. 000-52313)
10.22*	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)
10.23	Facility Lease-Purchase Agreement Dated as of August 9, 2013, Between Southaven Combined Cycle Generation LLC and TVA (Incorporated by reference to Exhibit 10.32 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)
10.24	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)
10.25*	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)

188

10.26*	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)
10.27†	TVA Compensation Plan Approved by the TVA Board on May 31, 2007 (Incorporated by reference to Exhibit 99.3 to TVA's Current Report on Form 8-K filed on December 11, 2007, File No. 000-52313)
10.28†	Supplemental Executive Retirement Plan (Incorporated by reference to Exhibit 10.1 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.29†	Amendment Dated as of August 16, 2011, to Supplemental Executive Retirement Plan (Incorporated by reference to Exhibit 10.1 to TVA’s Current Report on Form 8-K filed on August 22, 2011, File No. 000-52313)
10.30†	Executive Annual Incentive Plan (Incorporated by reference to Exhibit 10.3 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.31†	Executive Long-Term Incentive Plan (Incorporated by reference to Exhibit 10.4 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.32†	Long-Term Deferred Compensation Plan (Incorporated by reference to Exhibit 10.5 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.33†	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)
10.34†	Long-Term Retention Incentive Plan (Incorporated by reference to Exhibit 10.1 to TVA’s Quarterly Report on Form 10-Q for the quarter March 31, 2014, 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 Charles Pardee Accepted as of March 14, 2013 (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on April 5, 2013, File No. 000-52313)
10.37†	Offer Letter to Joseph P. Grimes, Jr., Dated as of June 18, 2013
10.38†	Deferred Agreement Between TVA and William D. Johnson Dated as of January 1, 2013
10.39†	First Deferral Agreement Between TVA and John M. Thomas, III, Dated as of December 4, 2009  (Incorporated by reference to Exhibit 10.7 to TVA’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010, File No. 000-52313)
10.40†	Second Deferral Agreement Between TVA and John M. Thomas, III, Dated as of September 27, 2010 (Incorporated by reference to Exhibit 10.40 to TVA’s Annual Report on Form 10-K for the year ended September 30, 2010, File No. 000-52313)
10.41†	Third Deferral Agreement Between TVA and John M. Thomas, III, Dated as of January 4, 2012 (Incorporated by reference to Exhibit 10.45 to TVA's Annual Report on Form 10-K for the year ended September 30, 2012, File No. 000-52313)
10.42†	Fourth Deferral Agreement Between TVA and John M. Thomas, III, Dated as of April 22, 2013 (Incorporated by reference to Exhibit 10.4 to TVA's Quarterly Report on Form 10-Q for the quarter ended June 30, 2013, File No. 000-52313)
10.43†	Fifth Deferral Agreement Between TVA and John M. Thomas, III, Dated as of February 27, 2014
10.44†	Deferred Agreement Between TVA and Charles G. Pardee Dated as of April 23, 2013
10.45†	Deferred Agreement Between TVA and Joseph P. Grimes, Jr., Dated as of September 5, 2013

189

10.46†	First Deferral Agreement Between TVA and Michael D. Skaggs Dated as of March 1, 2010 (Incorporated by reference to Exhibit 10.61 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)
10.47†	Second 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
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.  The Tennessee Valley Authority hereby undertakes to furnish supplementally copies of any of the omitted schedules and/or exhibits upon request by the Securities and Exchange Commission.

190

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, 2014		TENNESSEE VALLEY AUTHORITY
			(Registrant)
		By:	/s/ William D. Johnson
			William D. Johnson
			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.

191

Signature	Title	Date
/s/ William D. Johnson	President and Chief Executive Officer	November 14, 2014
William D. Johnson	(Principal Executive Officer)
/s/ John M. Thomas, III	Executive Vice President and	November 14, 2014
John M. Thomas, III	Chief Financial Officer
	(Principal Financial Officer)
/s/ Diane Wear	Vice President and Controller	November 14, 2014
Diane Wear	(Principal Accounting Officer)
/s/ Joe H. Ritch	Chair	November 14, 2014
Joe H. Ritch
/s/ Marilyn A. Brown	Director	November 14, 2014
Marilyn A. Brown
/s/ V. Lynn Evans	Director	November 14, 2014
V. Lynn Evans
/s/ Barbara S. Haskew	Director	November 14, 2014
Barbara S. Haskew
/s/ Richard C. Howorth	Director	November 14, 2014
Richard C. Howorth
/s/ C. Peter Mahurin	Director	November 14, 2014
C. Peter Mahurin
/s/ Michael R. McWherter	Director	November 14, 2014
Michael R. McWherter
/s/ William B. Sansom	Director	November 14, 2014
William B. Sansom

192

EXHIBIT INDEX

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, 2007, 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
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	$1,000,000,000 Spring Maturity Credit Agreement Dated as of June 25, 2012, among TVA, The Bank of New York Mellon as Administrative Agent, Letter of Credit Issuer, and a Lender, Bank of America, N.A., Canadian Imperial Bank of Commerce, New York Agency, First Tennessee Bank National Association, Morgan Stanley Bank, N.A., and Toronto Dominion (New York) LLC (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on June 28, 2012, File No. 000-52313)
10.2	Amendment Dated as of December 12, 2012, to $1,000,000,000 Spring Maturity Credit Agreement Dated as of June 25, 2012, among TVA, The Bank of New York Mellon as Administrative Agent, Letter of Credit Issuer, and a Lender, Bank of America, N.A., Canadian Imperial Bank of Commerce, New York Agency, First Tennessee Bank National Association, Morgan Stanley Bank, N.A., and Toronto Dominion (New York) LLC (Incorporated by reference to Exhibit 10.2 to TVA's Current Report on Form 8-K filed on December 17, 2012, File No. 000-52313)
10.3	$1,000,000,000 Winter Maturity Credit Agreement Dated as of December 13, 2012, Among TVA, Royal Bank of Canada, as Administrative Agent, Letter of Credit Issuer, and a Lender, The Royal Bank of Scotland plc, UBS AG, Stamford Branch, Mizuho Corporate Bank, Ltd., Wells Fargo Bank, National Association, The Bank of Nova Scotia, and PNC Bank, National Association (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on December 17, 2012, File No. 000-52313)
10.4	Assignment and Assumption Agreement Dated as of April 30, 2014, Between UBS AG, Stamford Branch, and Sumitomo Mitsui Banking Corporation Relating to $1,000,000,000 Winter Maturity Credit Agreement Dated as of December 13, 2012 (Incorporated by reference to Exhibit 10.2 to TVA’s Quarterly Report on Form 10-Q for the quarter March 31, 2014, File No. 000-52313)
10.5	$500,000,000 April 2018 Maturity Credit Agreement Dated as of April 5, 2013, 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 April 10, 2013, File No. 000-52313)
10.6	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)
10.7	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)
10.8	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 March 31, 2014, File No. 000-52313)
10.9	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)
10.10	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)

193

10.11	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)
10.12	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)
10.13	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)
10.14	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)
10.15	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)
10.16*	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)
10.17*	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)
10.18*	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)
10.19	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)
10.20	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)
10.21	Construction Management Agreement Dated as of January 17, 2012, Between John Sevier Combined Cycle Generation LLC and TVA (Incorporated by reference to Exhibit 10.3 to TVA's Quarterly Report on Form 10-Q for the quarter ended December 31, 2011, File No. 000-52313)
10.22*	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)
10.23	Facility Lease-Purchase Agreement Dated as of August 9, 2013, Between Southaven Combined Cycle Generation LLC and TVA (Incorporated by reference to Exhibit 10.32 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)
10.24	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)
10.25*	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)

194

10.26*	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)
10.27†	TVA Compensation Plan Approved by the TVA Board on May 31, 2007 (Incorporated by reference to Exhibit 99.3 to TVA's Current Report on Form 8-K filed on December 11, 2007, File No. 000-52313)
10.28†	Supplemental Executive Retirement Plan (Incorporated by reference to Exhibit 10.1 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.29†	Amendment Dated as of August 16, 2011, to Supplemental Executive Retirement Plan (Incorporated by reference to Exhibit 10.1 to TVA’s Current Report on Form 8-K filed on August 22, 2011, File No. 000-52313)
10.30†	Executive Annual Incentive Plan (Incorporated by reference to Exhibit 10.3 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.31†	Executive Long-Term Incentive Plan (Incorporated by reference to Exhibit 10.4 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.32†	Long-Term Deferred Compensation Plan (Incorporated by reference to Exhibit 10.5 to TVA’s Current Report on Form 8-K filed on January 6, 2009, File No. 000-52313)
10.33†	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)
10.34†	Long-Term Retention Incentive Plan (Incorporated by reference to Exhibit 10.1 to TVA’s Quarterly Report on Form 10-Q for the quarter March 31, 2014, 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 Charles Pardee Accepted as of March 14, 2013 (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on April 5, 2013, File No. 000-52313)
10.37†	Offer Letter to Joseph P. Grimes, Jr., Dated as of June 18, 2013
10.38†	Deferred Agreement Between TVA and William D. Johnson Dated as of January 1, 2013
10.39†	First Deferral Agreement Between TVA and John M. Thomas, III, Dated as of December 4, 2009  (Incorporated by reference to Exhibit 10.7 to TVA’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010, File No. 000-52313)
10.40†	Second Deferral Agreement Between TVA and John M. Thomas, III, Dated as of September 27, 2010 (Incorporated by reference to Exhibit 10.40 to TVA’s Annual Report on Form 10-K for the year ended September 30, 2010, File No. 000-52313)
10.41†	Third Deferral Agreement Between TVA and John M. Thomas, III, Dated as of January 4, 2012 (Incorporated by reference to Exhibit 10.45 to TVA's Annual Report on Form 10-K for the year ended September 30, 2012, File No. 000-52313)
10.42†	Fourth Deferral Agreement Between TVA and John M. Thomas, III, Dated as of April 22, 2013 (Incorporated by reference to Exhibit 10.4 to TVA's Quarterly Report on Form 10-Q for the quarter ended June 30, 2013, File No. 000-52313)
10.43†	Fifth Deferral Agreement Between TVA and John M. Thomas, III, Dated as of February 27, 2014
10.44†	Deferred Agreement Between TVA and Charles G. Pardee Dated as of April 23, 2013
10.45†	Deferred Agreement Between TVA and Joseph P. Grimes, Jr., Dated as of September 5, 2013
10.46†	First Deferral Agreement Between TVA and Michael D. Skaggs Dated as of March 1, 2010 (Incorporated by reference to Exhibit 10.61 to TVA's Annual Report on Form 10-K for the year ended September 30, 2013, File No. 000-52313)

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10.47†	Second 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
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.  The Tennessee Valley Authority hereby undertakes to furnish supplementally copies of any of the omitted schedules and/or exhibits upon request by the Securities and Exchange Commission.

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EX-3.2

EXHIBIT 3.2

BYLAWS

OF

THE TENNESSEE VALLEY AUTHORITY

PREAMBLE

These Bylaws of the Tennessee Valley Authority are adopted by the Board of Directors of the Tennessee Valley Authority in accordance with Section 4(e) of the Tennessee Valley Authority Act of 1933, as amended (said Act hereafter referred to as the “TVA Act”).

ARTICLE I

Board of Directors

Section 1.1Number; Selection of Chair. In accordance with Section 2(a)(1) of the TVA Act, the Board of Directors shall consist of nine members appointed by the President of the United States by and with the advice and consent of the United States Senate. The Board of Directors shall select one of its members to serve as Chair of the Board. The Chair shall serve a term of two years unless the Board decides otherwise. The term of the first Chair selected under the provisions of Section 2(a)(2) of the TVA Act shall expire on May 18, 2008, and each subsequent term of a Chair of the Board shall expire on May 18 of each subsequent even-numbered calendar year, unless the Board decides otherwise. A Chair’s successor shall be selected by the Board at least thirty (30) calendar days prior to the end of the term of the then current Chair; provided, however, that if the position of Chair should become vacant prior to the end of a term due to resignation or any other reason, the Board shall, not later than thirty (30) calendar days after the date upon which such vacancy occurs, select a new Chair to serve out the remainder of the current term.

Section 1.2Regular Meetings. Regular meetings of the Board of Directors will be held at least four times each calendar year at such places and at such times as the Board of Directors may from time to time determine, consistent with the requirements of Section 2(g)(2) of the TVA Act. Notice of, and agendas for, regular meetings shall be given to all Board members in advance of the meeting and shall be publicly disclosed in advance in accordance with the requirements of the Government in the Sunshine Act, as amended.

Section 1.3Special Meetings. Special meetings of the Board of Directors may be called by the Chair of the Board or a majority of the members of the Board of Directors then in office and may be held at any time, date or place, as the person or persons calling the meeting shall fix. Notice of the time, date and place of, and agenda for, such meeting shall be given to all members in advance of the meeting and shall be publicly disclosed in advance in accordance with the requirements of the Government in the Sunshine Act, as amended.

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Section 1.4Remote Attendance at Meetings. Members of the Board of Directors, or any committee designated by the Board, may participate in a meeting of such Board or committee by means of conference telephone, audio/video transmission, or similar communications medium, by means of which all persons participating in the meeting can simultaneously communicate on a real-time basis with all other participants, and participation in a meeting pursuant to this bylaw shall constitute presence in person at such meeting; provided however, that personal attendance of Board members at meetings of the Board is strongly encouraged. The proceedings of any Board meeting covered by this Section 1.4 shall be public, and proper notice of the time, date, and place of, and agenda for, said meeting shall be publicly disclosed in advance in accordance with the requirements of the Government in the Sunshine Act, as amended.

Section 1.5Quorum; Vote Required for Action. In accordance with the provisions of

Section 2(e) of the TVA Act, five of the members of the Board shall constitute a quorum for the transaction of business. Except as otherwise provided in these Bylaws or required by law, the vote of a majority of the members either physically present or participating by remote attendance in accordance with Section 1.4 of these Bylaws shall be the act of the Board of Directors.

Section 1.6Vacancies. In the event that vacancies cause the Board to have fewer than five members for any period of time, during any such period of time the members in office may, as a Board without a quorum, continue to exercise those powers of the Board which are necessary to assure continuity of operations of the Corporation along the lines established while the Corporation was guided by a quorum of the Board, but shall not have the authority to direct the Corporation into new areas of activity, to embark on new programs, or to change the Corporation’s existing direction.

Section 1.7Organization. The Meetings of the Board of Directors shall be presided over by the Chair of the Board. In the absence of the Chair at a meeting of the Board, the Chair of the audit committee shall preside.

Section 1.8Notational Approvals by Individual Directors. As long as personal notice of said action for consideration by the Board of Directors, or a committee thereof, is provided to individual members of the Board, or of the appropriate committee thereof, by electronic mail or as otherwise specified by said individual Board member, any action required or permitted to be taken at any meeting of the Board, or of any committee thereof, may be taken without a meeting if a majority of all members of the Board or such committee, as the case may be, approve such action independently and individually in writing. Members shall normally have seven calendar days during which they are to submit their individual votes unless the Chair of the Board or the Chair of said committee of the Board, as appropriate, has specified that the deadline for voting on a particular notational item will be a different number of calendar days; provided, that in no event shall the deadline be fewer than three calendar days. The writings constituting such approval shall be filed with the minutes of proceedings of the next Board or committee meeting as appropriate.

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Section 1.9Powers of the Board of Directors. The principal responsibilities of the Board of Directors are to establish the broad strategies, goals, objectives, long-range plans, and policies of the Corporation in a manner consistent with the missions set forth in the TVA Act and to ensure that those are achieved by the Chief Executive Officer. Accordingly, the Board of Directors has those powers and authorities vested in the Board under the provisions of the TVA Act or under other provisions of law to carry out those principal responsibilities. The Board of Directors may, to the extent permitted by law, delegate authorities of the Board to the Chief Executive Officer or other officials of the Corporation.

Section 1.10Authorities of the Chair of the Board. The principal responsibilities of the Chair of the Board are not executive in nature and are those vested in the Chair of the Board under these Bylaws. Accordingly, the Chair of the Board has those authorities as are necessary or appropriate to carry out the aforementioned principal responsibilities.

Section 1.11Compensation of Board Members. Members shall be compensated in accordance with the provisions of Section 2(f) of the TVA Act and other applicable provisions of law.

ARTICLE II

Committees

Section 2.1Committees. There shall, as a minimum, be an audit committee of Board members as required by Section 2(g)(1)(I) of the TVA Act. In addition, the Board may, from time to time by resolution passed by a majority of the Board, designate one or more committees of Board members and specify the responsibilities and duties of each such committee. The Chair of the Board shall appoint Board members to serve on each committee. All appointees for the membership of committees, and any changes to committee membership, shall be submitted by the Chair of the Board to the Board for its approval as a single slate of appointees. The Chair of the Board shall select and designate which Board member on each committee shall serve as Chair of said committee. The Chairs and members of committees shall serve terms that run concurrently with the term of the Chair of the Board who appointed them to those positions.

Section 2.2Committee Rules. Unless the Board of Directors otherwise provides, each committee designated by the Board may make, alter and repeal rules for conduct of its business. In the absence of such rules each committee shall conduct its business in the same manner as the Board of Directors conducts its business.

Section 2.3Committee Retention of Outside Advisors. It is recognized that the committees of the Board may require the engagement of outside advisors with certain expertise to assist such committees and the Board in competently addressing their responsibilities and duties. The engagement of outside advisors will be made in accordance with Board-approved guidance. Because the Board deems it prudent and appropriate to ensure stability and continuity in its outside advisors in light of transitions in

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membership on the Board, the termination of the engagement of an outside advisor during the term of an engagement contract with a Board committee will require approval by the Board of Directors. To provide for notice and consideration, a vote on a motion to approve any such termination shall be taken no earlier than the next regularly scheduled meeting of the Board following the meeting at which such motion is presented. None of the provisions of this section are applicable to the audit committee of the Board of Directors, which shall have independent authority to engage and terminate engagement of its outside advisors.

ARTICLE III

Officers

Section 3.1Chief Executive Officer; Officers; Selection; Qualifications; Resignation; Vacancies. The Board of Directors shall choose and appoint a person to serve as Chief Executive Officer of the Tennessee Valley Authority in accordance with the requirements and qualifications specified for such position in Section 2(h) of the TVA Act. The Chief Executive Officer shall serve at the pleasure of the Board of Directors. With the advice and consent of the Board in accordance with Section 3(a) of the TVA Act, the Chief Executive Officer shall choose and appoint such officers, managers, assistant managers, employees, attorneys, and agents as are necessary for the transaction of the business of the Corporation.

Section 3.2Authorities and Duties of Chief Executive Officer. The principal responsibilities of the Chief Executive Officer are to achieve the broad strategies, goals, objectives, long-range plans, and policies established by the Board of Directors for the Corporation and to ensure the continuity and reliability of the Corporation’s operations. Accordingly, the Chief Executive Officer has all powers, authorities, and duties necessary or appropriate to carry out those principal responsibilities, including but not limited to those to carry out projects and activities approved by the Board of Directors or to maintain continuity and/or reliability of ongoing operations. In addition, the Chief Executive Officer shall have all powers, authorities, and duties which are either: (i) delegated to the Chief Executive Officer by action of the Board; or (ii) vested in the Chief Executive Officer under the provisions of the TVA Act or any other provision of law.

Section 3.3Primary Spokesperson. The Chief Executive Officer shall be the Corporation’s primary spokesperson in communications with external individuals and entities.

Section 3.4Compensation. In accordance with the provisions of Section 2(i) of the TVA Act, the Board of Directors shall approve: (i) a compensation plan that specifies all compensation (including salary or any other pay, bonuses, benefits, incentives, and any other form of remuneration) for the Chief Executive Officer and employees of the Corporation and (ii) on the recommendation of the Chief Executive Officer, shall approve the salaries of employees whose annual salaries would be in excess of the

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annual rate payable for positions at level IV of the Executive Schedule under section 5315 of title 5, United States Code. In accordance with the provisions of Section 2(g)(1)(G) of the TVA Act, the Board of Directors shall approve all compensation (including salary or any other pay, bonuses, benefits, incentives, and any other form of remuneration) of all managers and technical personnel that report directly to the Chief Executive Officer (including any adjustment to compensation).

Section 3.5Interim Chief Executive Officer. The Chief Executive Officer shall designate to the Board of Directors in writing which executive officer of the Corporation, or what succession of executive officers of the Corporation, is authorized to serve in the position of Chief Executive Officer on an interim basis in the event that the Chief Executive Officer becomes unable to carry out his duties and responsibilities due to incapacitation, death, or absence for any other reason. In such an event, the designated executive officer of the Corporation shall serve as the Chief Executive Officer until such time as the Board of Directors may decide otherwise. The Chief Executive Officer may, from time to time, revise the aforementioned designation by informing the Board of Directors of such change in writing.

ARTICLE IV

TVA Board Practices System

Section 4.1TVA Board Practices System. The “TVA Board Practices System” shall contain practices approved by the Board for inclusion in the System which govern various Board and Board Committee processes and activities or interpret provisions of these Bylaws. These practices provide guidance to members of the Board and provide guidance or delegate additional general authorities to the Chief Executive Officer in those cases where an amendment to these Bylaws to accomplish such purposes is not deemed to be necessary.

Section 4.2Adoption of New TVA Board Practices. The adoption by the Board of Directors of any new TVA Board Practice shall require a vote in the affirmative by not less than a majority of those members of the Board voting.

ARTICLE V

Indemnification

Section 5.1Right to Indemnification. The Corporation shall indemnify and hold harmless, to the fullest extent permitted by applicable law as it presently exists or may hereafter be amended in a manner more favorable to indemnitees, any person (an “Indemnitee”) who was or is made or is threatened to be made a party or is otherwise involved in any threatened or pending claim, action, suit or proceeding, whether civil, criminal, administrative or investigative (a “proceeding”), by reason of the fact that he, she, or a person for whom he or she is the legal representative, is or was a director or officer of the Corporation or, while a director or officer of the Corporation, is or was serving at the request of the Corporation as a director, officer, employee or agent of another corporation or of a partnership, joint venture, trust, enterprise or nonprofit entity, including service with respect to employee benefit plans, against all liability

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and loss suffered and expenses (including attorneys’ fees) reasonably incurred by such Indemnitee. Notwithstanding the preceding sentence, except as otherwise provided in Section 5.3, the Corporation shall be required to indemnify an Indemnitee in connection with a proceeding (or part thereof) commenced by such Indemnitee only if the commencement of such proceeding (or part thereof) by the Indemnitee was authorized by the Board of Directors of the Corporation. At the Indemnitee’s election, the Corporation shall provide or arrange for legal representation of the Indemnitee in defending any proceeding against said Indemnitee in advance of its final disposition. The indemnification provided by this Article V shall inure to the benefit of the heirs, executors and administrators of the Indemnitee.

Section 5.2Payment of Expenses. The Corporation shall pay the expenses incurred personally by an Indemnitee in defending any proceeding in advance of its final disposition, provided, however, that any payment of such expenses in advance of the final disposition of the proceeding shall be made only upon receipt of an undertaking by the Indemnitee to repay all amounts advanced if it should ultimately be determined that the Indemnitee is not entitled to be indemnified under this Article V or otherwise.

Section 5.3Other Sources. The Corporation’s obligation, if any, to indemnify or to advance expenses to any Indemnitee who was or is serving at its request as a director, officer, employee or agent of another corporation, partnership, joint venture, trust, enterprise or nonprofit entity shall be reduced by any amount such Indemnitee may collect as indemnification or advancement of expenses from such other corporation, partnership, joint venture, trust, enterprise or nonprofit enterprise.

Section 5.4Amendment or Repeal. Any repeal or modification of the foregoing provisions of this Article V shall not adversely affect any right or protection hereunder of any Indemnitee in respect of any act or omission occurring prior to the time of such repeal or modification.

Section 5.5Other Indemnification and Prepayment of Expenses. This Article V shall not limit the right of the Corporation, to the extent and in the manner permitted by law, to indemnify and to advance expenses to persons other than Indemnitees when and as authorized by appropriate corporate action.

Section 5.6Indemnification Contracts. The Board of Directors is authorized to cause the Corporation to enter into indemnification contracts with any director, officer, employee or agent of the Corporation, or any person serving at the request of the Corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, including employee benefit plans, providing indemnification rights to such person. Such rights may be greater than those provided in this Article V.

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Section 5.7Effect of Amendment. Any amendment, repeal or modification of any provision of this Article V shall be prospective only, and shall not adversely affect any right or protection conferred on a person pursuant to this Article V and existing at the time of such amendment, repeal or modification.

Section 5.8Insurance. The Corporation may purchase and maintain insurance on behalf of any person who is or was or has agreed to become a director, officer, employee or agent of the Corporation, or is or was serving at the request of the Corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise against any liability asserted against him or her and incurred by him or her or on his or her behalf in any such capacity, or arising out of his or her status as such, whether or not the Corporation would have the power to indemnify him or her against such liability under the provisions of this Article V.

Section 5.9Savings Clause. If this Article V or any portion hereof shall be invalidated on any ground by any court of competent jurisdiction, then the Corporation shall nevertheless indemnify each director and officer of the Corporation as to costs, charges and expenses (including attorneys’ fees), judgments, fines and amounts paid in settlement with respect to any action, suit or proceeding, whether civil, criminal, administrative or investigative, including an action by or in the right of the Corporation, to the full extent permitted by any applicable portion of this Article V that shall not have been invalidated and to the full extent permitted by applicable law.

ARTICLE VI

Miscellaneous

Section 6.1Fiscal Year. The fiscal year of the Corporation shall be October 1 through September 30, unless specified otherwise by Act of Congress.

Section 6.2Seal. The corporate seal shall have the name of the Corporation inscribed thereon and shall be in such form as may be approved from time to time by the Board of Directors.

Section 6.3Conflict-of-Interest Policy. In accordance with the requirements of Section 2(g)(1)(E) of the TVA Act, the Board of Directors shall maintain and may, from time to time, revise a conflict-of-interest policy applicable to members of the Board, the Chief Executive Officer, and all employees of the Corporation. Any revisions to the aforementioned conflict-of-interest policy adopted by the Board of Directors shall be submitted to the United States Congress.

Section 6.4Form of Records. Any records maintained by the Corporation in the regular course of its business, including its books of account and minute books, may be kept on, or be in the form of any information storage device, provided that the records so kept can be converted into clearly legible form within a reasonable time.

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Section 6.5Reliance Upon Books and Records. A member of the Board of Directors, or a member of any committee designated by the Board of Directors shall, in the performance of his or her duties, be fully protected in relying in good faith upon records of the Corporation and upon such information, opinions, reports or statements presented to the Corporation by any of the Corporation’s officers or employees, or committees of the Board of Directors, or by any other person as to matters the member reasonably believes are within such other person’s professional or expert competence and who has been selected with reasonable care by or on behalf of the Corporation.

Section 6.6TVA Act Governs. In the event of any conflict between the provisions of the TVA Act, or other applicable provisions of law, and these Bylaws, the provisions of the TVA Act, or other applicable provisions of law, shall govern.

Section 6.7Severability. If any provision of these Bylaws shall be held to be invalid, illegal, unenforceable or in conflict with the provisions of the TVA Act, or other applicable provisions of law, then such provision shall nonetheless be enforced to the maximum extent possible consistent with such holding and the remaining provisions of these Bylaws (including without limitation, all portions of any section of these Bylaws containing any such provision held to be invalid, illegal, unenforceable or in conflict with the TVA Act, or other applicable provisions of law, that are not themselves invalid, illegal, unenforceable or in conflict with the TVA Act, or other applicable provisions of law) shall remain in full force and effect.

Section 6.8Amendments. To the extent consistent with the provisions of the TVA Act, the Board of Directors shall have the power to adopt, amend or repeal Bylaws of the Corporation. To provide for notice and consideration, a vote on a motion to approve any amendments of the Bylaws shall be taken no sooner than the next meeting of the Board following the meeting at which such motion is presented.

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EX-10.37

EXHIBIT 10.37

Tennessee Valley Authority, 400 West Summit Hill Drive, Knoxville, Tennessee 37902-1401

June 17, 2013

Mr. Joseph P. Grimes, Jr.

753 Harrison Road

Villanova, Pennsylvania 19085

Dear Mr. Grimes:

I am pleased to offer you the position of Executive Vice President and Chief Nuclear Officer with the Tennessee Valley Authority (“TVA”) in Chattanooga, Tennessee. This position is responsible for directing and managing TVA’s Nuclear Power Group and ensuring a stable base load from all of TVA’s nuclear operating units. Responsibilities include planning and directing all organizational activities related to nuclear power production, nuclear power plant operations, maintenance, modifications, and all nuclear support services and engineering activities.

Your commencement date as Executive Vice President and Chief Nuclear Officer will be September 3, 2013. Upon employment in this position, TVA will provide you an annual salary of $535,000, which will be payable on a biweekly basis.

Additionally, you will be included as a participant in TVA’s Executive Annual and Long-Term Incentive Plans. Under the Annual Incentive Plan, your annual incentive opportunity will be 80 percent of your annual salary beginning in fiscal year 2014 (October 1, 2013 through September 30, 2014). Under the Long-Term Incentive Plan, your incentive opportunity will be 110 percent of your annual salary beginning with the three-year performance cycle (FY 2012-2014) ending on September 30, 2014 (October 1, 2012 through September 30, 2014). Your long-term incentive awards will be prorated based on the number of full months you participate in the three-year performance cycles ending in September 2014 and September 2015, respectively. You will be eligible to receive a full award under the Long-Term Incentive Plan beginning with the performance cycle ending in FY 2016 (FY 2014-2016). Actual annual and long-term incentive awards are based on performance measured against performance goals established at the beginning of each performance period. The incentive awards are generally paid in the first quarter of the fiscal year following the fiscal year in which they are earned.

Joseph P. Grimes, Jr.

Page 2

June 17, 2013

TVA will also enter into a Long-Term Deferred Compensation Plan (LTDCP) agreement with you that will provide annual deferred compensation credits to cover a service period beginning on the effective date of employment and ending December 31, 2015. Under the agreement, an initial credit of $250,000 will be made to an account in your name as soon as practical following execution of the agreement. Subsequent credits of $150,000 each will be made to your account on January 1, 2014 and January 1, 2015. You will become fully vested in the balance of your account if you remain employed by TVA through the expiration of the agreement on December 31, 2015, after which the account will be distributed in accordance with the election you make at the time you enter into the agreement.

Due to the nature of this position, you will also be included as a participant in TVA's Supplemental Executive Retirement Plan (SERP) at the Tier 1 level with the following provision:

• The “Qualified Plan Offset” will be calculated based on the pension benefit you would be eligible to receive as a participant in TVA's Cash Balance Benefit Structure.

At your request, we will provide a general outline of how the SERP calculation works for you to use in your consideration of this offer.

In the event TVA terminates your employment without cause, other than due to disability or death, TVA will pay you a lump-sum payment in an amount equal to one year's annual salary. In such event, this lump-sum will be paid to you within sixty (60) days following the effective date of your separation from service. For purposes of this provision, termination without cause includes constructive termination which will be deemed to occur if you terminate your employment because you are asked to take a new position with TVA with a material reduction in level of authority, duties, compensation, and benefits. This provision shall not apply, and no lump-sum payment will be made, in the event you voluntarily terminate your employment, voluntarily retire, or your employment is terminated “for cause” (as defined below).

For purposes of this offer letter, termination “for cause” shall be defined as termination as a result of any act on your part resulting in or involving any of the following: (1) insubordination, intentional neglect of duties, or refusal to cooperate with investigations of your or TVA's business practices; (2) criminal indictment or conviction of a felony or crime of moral turpitude; or (3) misconduct involving dishonesty, fraud, or gross negligence that directly results in significant economic or reputational harm to TVA.

TVA will also provide you a biweekly vehicle allowance, totaling approximately $11,700 annually, toward the purchase or lease of a vehicle and operating fees, maintenance, repairs, accidents, and insurance. This allowance is considered a taxable benefit and will be subject to withholding and any other applicable taxes.

Joseph P. Grimes, Jr.

Page 3

June 17, 2013

In connection with your move to TVA's headquarters in Chattanooga, Tennessee, TVA will pay for the actual and reasonable travel and moving expenses, including home closing costs, for you and your immediate family. TVA's relocation services program will also be available to assist you in the sale of your present home. In addition to relocation benefits, TVA will provide you a one-time recruitment and relocation incentive payment in the amount of $200,000, which will be paid to you in a lump sum as soon as practical following the commencement of your employment. These relocation benefits and the one-time recruitment and relocation incentive payment must be repaid in full to TVA if, within one year of the effective date of your employment, (i) you voluntarily terminate employment unless the separation is for reasons beyond your control and acceptable to TVA, or (ii) if you are terminated for cause.

You will be entitled to annual leave accrued at the initial rate of four (4) hours per pay period, sick leave accrued at the rate of four (4) hours per pay period, and paid holidays in accordance with applicable Federal leave laws and laws establishing Federal holidays contained in Title V of the United States Code. In your capacity as Executive Vice President and Chief Nuclear Officer, it is recognized that you will be required to work outside and beyond normal work hours. Accordingly, administrative leave for additional time off may be made available as agreed upon between you and the Chief Generation Officer.

During your employment, you will be eligible to participate in all TVA-sponsored employee benefits plans and qualified retirement plans available to new management and specialist employees at TVA. Information and materials regarding these plans, including the benefits provided under them, will be provided to you.

Your employment will be subject to the usual employment procedures and satisfactory results of a security investigation, which will include a drug screen. This position will also require, and is subject to your receiving, a top secret security clearance and a nuclear security/safeguards clearance.

If you have questions, or if I can be of assistance in any way, please do not hesitate to call me. We look forward to your acceptance and joining the TVA team.

Please sign below indicating your acceptance of this offer.

Sincerely,

/s/ Katherine J. Black

Katherine J. Black

Vice President, Human Resources

/s/ Joseph P. Grimes, Jr.June 18, 2013

Joseph P. Grimes, Jr.Acceptance Date

EX-10.38

EXHIBIT 10.38

DEFERRAL AGREEMENT

William D. Johnson

The TVA Board of Directors has approved your participation in TVA’s Long-Term Deferred Compensation Plan (Plan) under the following terms:

		Vesting Date(s)	Vesting Amount
Duration of deferral agreement:	Two years nine months
First compensation credit:	$300,000 (01/01/2013)	09/30/2013	Balance of account on vesting date
Second compensation credit:	$300,000 (10/01/2013)	09/30/2014	Balance of account on vesting date
Third and final compensation credit:	$300,000 (10/01/2014)	09/30/2015	Balance of account on vesting date
Total credits over deferral period:	$900,000
Expiration date:	09/30/2015

Please read the following provisions carefully and indicate your approval by signing at the designated place below.

________________________________________________________________________________

As a participant in the Plan, I hereby agree to be bound by the following terms and conditions:

Deferred compensation credits as stated above will be made to an account in my name to cover a service period, beginning January 1, 2013, and ending on September 30, 2015, provided that I remain employed by TVA through September 30, 2015. I shall be entitled to compensation credits including interest and returns on the vesting dates as stated in the above schedule provided that I remain employed by TVA through each of the vesting periods. At the end of each vesting period, the balance in my account, including interest or return as provided below, will be paid to me in a lump sum payment.

I understand that I must be an employee of TVA at the end of each vesting period stated above, or no payments or transfers under the Plan will be made by TVA, and any unvested credits to my account will be extinguished. However, in the event that TVA terminates my employment during the term of this agreement through no act or delinquency of my own, this agreement is terminated as of the date of my termination and no further credits will be made under it and any credits in my account from this agreement, including interest or return as provided below, at the time of termination will become vested. If TVA terminates my employment for cause prior to the expiration of this agreement, no further payments or credits will be made and my account balance will be extinguished. In the event of my death during the term of this agreement, my account balance will be paid to the person identified on my beneficiary designation form or, in the absence of such designation, to my estate, in a manner permitted by applicable IRS rules.

Interest will be credited to the balance reflected in my LTDCP account on the same basis as interest is calculated and credited under the TVA Deferred Compensation Plan. In the alternative, I may choose to have the balance of my LTDCP account adjusted based on the return of the funds I select under the same conditions as are contained in TVA’s Deferred Compensation Plan. I understand that I am solely responsible for the risk associated with any return elections that I make.

The Plan may be amended or discontinued by the Board. If the Board elects to discontinue the Plan, any credits to my account as of the date of termination of the Plan will be paid to me in accordance with applicable IRS rules.

I understand that nothing contained in this agreement shall be construed as conferring the right to continue in the employment of TVA as an executive or in any other capacity and that the method of payment stated above is final (not revocable).

/s/ William D. Johnson1/2/13

William D. JohnsonDate

EX-10.43

EXHIBIT 10.43

DEFERRAL AGREEMENT

John Madison Thomas III

TVA’s President and Chief Executive Officer has approved your participation in TVA’s Long-Term Deferred Compensation Plan (Plan) under the terms and conditions stated below.

Duration of deferral agreement	Ten Months
First and only compensation credit	$200,000 (03/01/2014)
Total credits	$200,000
Expiration date	12/31/2014

Please read the following provisions carefully and indicate your approval by signing at the designated place below.

________________________________________________________________________________________

As a participant in the Plan, I hereby agree to be bound by the following terms and conditions:

A deferred compensation credit in the amount of $200,000 will be made to an account in my name to cover a service period beginning March 1, 2014, and ending December 31, 2014. Upon the expiration of this agreement, the entire amount credited to my account under this agreement, including interest or return as provided below, will be paid to me in a single lump sum cash payment.

I understand that I must remain employed by TVA through the expiration of this agreement, or no payments or transfers under the Plan will be made by TVA, and any credits to my account will be extinguished. However, in the event that TVA terminates my employment during the term of this agreement through no act or delinquency of my own, this agreement will be terminated as of the date of my termination and any credits in my account from this agreement, including interest or return as provided below, at the time of termination will become vested. If TVA terminates my employment for cause prior to the expiration of this agreement, no payments will be made and my account balance will be extinguished. In the event of my death during the term of this agreement, my account balance will be paid to the person identified on my beneficiary designation form or, in the absence of such designation, to my estate, in a manner permitted by applicable IRS rules.

Interest will be credited to the balance reflected in my deferral account associated with this agreement on the same basis as interest is calculated and credited under the TVA Deferred Compensation Plan. In the alternative, I may choose to have the balance of my deferral account associated with this agreement adjusted based on the return of the funds I select under the same conditions as are contained in TVA’s Deferred Compensation Plan. I understand that I am solely responsible for the risk associated with any return elections that I make.

The Plan may be amended or discontinued by the Board. If the Board elects to discontinue the Plan, any credits to my account as of the date of termination of the Plan will be paid to me in accordance with applicable IRS rules

I understand that nothing contained in this agreement shall be construed as conferring the right to continue in the employment of TVA in any capacity and that the payment distribution is final (not revocable).

/s/ John Madison Thomas III2/27/14

John Madison Thomas IIIDate

EX-10.44

EXHIBIT 10.44

DEFERRAL AGREEMENT

Charles Graham Pardee

TVA’s President and Chief Executive Officer has approved your participation in TVA’s Long-Term Deferred Compensation Plan (Plan) under the following terms:

Duration of deferral agreement	Three years and eight months
First compensation credit	$200,000 (05/01/2013)
Second and third compensation credits	$200,000 each (01/01/2014, 01/01/2015 and 01/01/2016)
Total credits over service period	$800,000
Expiration date	12/31/2016

Please read the following provisions carefully and indicate your approval by signing at the designated place below.

___________________________________________________________________________________________

As a participant in the Plan, I hereby agree to be bound by the following terms and conditions:

Annual deferred compensation credits as stated above will be made to an account in my name to cover a service period beginning May 1, 2013 and ending on December 31, 2016, provided that I remain employed by TVA through the expiration of the agreement on December 31, 2016. Upon the expiration of this agreement, the entire amount credited to my account, including interest or return as provided below, will be paid to me in a lump sum unless I elect below to have the balance of my Long-Term Deferred Compensation Plan (LTDCP) account transferred to my TVA deferred compensation account.

I understand that I must be an employee of TVA at the time of the expiration of this agreement, or no payments or transfers under the Plan will be made by TVA, and any credits to my account will be extinguished. However, in the event that TVA terminates my employment during the term of this agreement through no act or delinquency of my own, this agreement is terminated as of the date of my termination and no further credits will be made under it and any credits in my account from this agreement, including interest or return as provided below, at the time of termination will become vested. If I elect below to have the balance of my LTDCP account transferred to my TVA deferred compensation account, all credits from this agreement will be paid out to me in accordance with my deferral election applicable to such credits or in accordance with otherwise applicable IRS rules. If TVA terminates my employment for cause prior to the expiration of this agreement, no payments will be made and my account balance will be extinguished. In the event of my death during the term of this agreement, my account balance will be paid to the person identified on my beneficiary designation form or, in the absence of such designation, to my estate, in a manner permitted by applicable IRS rules.

Interest will be credited to the balance reflected in my LTDCP account on the same basis as interest is calculated and credited under the TVA Deferred Compensation Plan. In the alternative, I may choose to have the balance of my LTDCP account adjusted based on the return of the funds I select under the same conditions as are contained in TVA’s Deferred Compensation Plan. I understand that I am solely responsible for the risk associated with any return elections that I make.

The Plan may be amended or discontinued by the Board. If the Board elects to discontinue the Plan, any credits to my account as of the date of termination of the Plan will be paid to me in accordance with applicable IRS rules. I elect the following option for payment upon expiration of this agreement:

___ __ Balance of account to be paid to me in a lump sum

___X__ Balance of account to be transferred to my TVA Deferred Compensation Plan account

I understand that nothing contained in this agreement shall be construed as conferring the right to continue in the employment of TVA as an executive or in any other capacity and that the payment election I have made is final (not revocable).

/s/ Charles Graham Pardee4.23.13

Charles Graham PardeeDate

EX-10.45

EXHIBIT 10.45

DEFERRAL AGREEMENT

Joseph Patrick Grimes, Jr.

TVA’s President and Chief Executive Officer has approved your participation in TVA’s Long-Term Deferred Compensation Plan (Plan) under the following terms:

Duration of deferral agreement	Two years and four months
First compensation credit	$250,000 (09/01/2013)
Second and third compensation credits	$150,000 each (01/01/2014 and 01/01/2015)
Total credits over service period	$550,000
Expiration date	12/31/2015

Please read the following provisions carefully and indicate your approval by signing at the designated place below.

___________________________________________________________________________________________

As a participant in the Plan, I hereby agree to be bound by the following terms and conditions:

Annual deferred compensation credits as stated above will be made to an account in my name to cover a service period beginning September 1, 2013 and ending on December 31, 2015, provided that I remain employed by TVA through the expiration of the agreement on December 31, 2015. Upon the expiration of this agreement, the entire amount credited to my account, including interest or return as provided below, will be paid to me in a lump sum unless I elect below to have the balance of my Long-Term Deferred Compensation Plan (LTDCP) account transferred to my TVA deferred compensation account.

I understand that I must be an employee of TVA at the time of the expiration of this agreement, or no payments or transfers under the Plan will be made by TVA, and any credits to my account will be extinguished. However, in the event that TVA terminates my employment during the term of this agreement through no act or delinquency of my own, this agreement is terminated as of the date of my termination and no further credits will be made under it and any credits in my account from this agreement, including interest or return as provided below, at the time of termination will become vested. If I elect below to have the balance of my LTDCP account transferred to my TVA deferred compensation account, all credits from this agreement will be paid out to me in accordance with my deferral election applicable to such credits or in accordance with otherwise applicable IRS rules. If TVA terminates my employment for cause prior to the expiration of this agreement, no payments will be made and my account balance will be extinguished. In the event of my death during the term of this agreement, my account balance will be paid to the person identified on my beneficiary designation form or, in the absence of such designation, to my estate, in a manner permitted by applicable IRS rules.

Interest will be credited to the balance reflected in my LTDCP account on the same basis as interest is calculated and credited under the TVA Deferred Compensation Plan. In the alternative, I may choose to have the balance of my LTDCP account adjusted based on the return of the funds I select under the same conditions as are contained in TVA’s Deferred Compensation Plan. I understand that I am solely responsible for the risk associated with any return elections that I make.

The Plan may be amended or discontinued by the Board. If the Board elects to discontinue the Plan, any credits to my account as of the date of termination of the Plan will be paid to me in accordance with applicable IRS rules. I elect the following option for payment upon expiration of this agreement:

______ Balance of account to be paid to me in a lump sum

___X__ Balance of account to be transferred to my TVA Deferred Compensation Plan account

I understand that nothing contained in this agreement shall be construed as conferring the right to continue in the employment of TVA as an executive or in any other capacity and that the payment election I have made is final (not revocable).

/s/ Joseph Patrick Grimes, Jr.9.5.13

Joseph Patrick Grimes, Jr.Date

EX-14.2

EXHIBIT 14.2

Tennessee Valley Authority

Conflict of Interest Policy

The Board of Directors of the Tennessee Valley Authority (TVA) adopts this Conflict of Interest Policy which applies to Board members, the Chief Executive Officer (CEO), and employees of TVA.

I.General Principles

Members of the Board of Directors will hold themselves and each other to the highest standards of integrity, honesty, and ethical conduct. Similarly, the Board will require that the CEO and all TVA employees shall conduct themselves with integrity and follow ethical and conflict of interest policies established by TVA and the Federal Government in their business practices, actions, and transactions.

II.Policy Applicable to All TVA Employees

The Board of Directors reaffirms that all TVA employees, including TVA Directors and the CEO, shall comply with applicable conflict of interest laws, regulations, and policies which govern their business and personal conduct, including but not limited to the general federal conflict of interest statute (18 U.S.C. Section 208) and the Standards of Ethical Conduct for Employees of the Executive Branch (5 C.F.R. Part 2635).

III.Additional Policy Applicable to TVA Directors and the CEO

In addition to the law and policy applicable to all TVA employees, TVA Directors and the CEO shall comply with the following additional policy restricting the holding of certain financial interests:

1. For purposes of this policy, “financial interest” means an interest of a person, or of a person’s spouse or minor child, arising by virtue of investment or credit relationship, ownership, employment, consultancy, or fiduciary relationship such as director, trustee, or partner. However, financial interest does not include an interest in TVA or any interest:

◦ comprised solely of a right to payment of retirement benefits resulting from former employment or fiduciary relationship,

◦ arising solely by virtue of cooperative membership or similar interest as a consumer in a distributor of TVA power, or

◦ arising by virtue of ownership of publicly traded securities:

▪ of any single entity with a value of $25,000 or less, or

▪ of a parent entity with one or more subsidiaries covered by this Policy that collectively contribute to a proportionate owned value of the parent’s securities in an amount of $25,000 or less, or

▪ of a diversified mutual fund with a value of any amount, or

▪ of a sector mutual fund, exchange traded fund, or similar investment fund with a value of any amount, provided the fund is not primarily focused on the wholesale or retail generation, transmission, or sale of electricity in North America).

1

2. Directors and the CEO shall not hold a financial interest in any distributor of TVA power.

3. Directors and the CEO shall not hold a financial interest in 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.

4. Directors and the CEO shall not hold a financial interest in 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.

5. Any action taken or interest held that creates, or may reasonably be perceived as creating, a conflicting financial interest restricted by this additional policy applicable to TVA Directors and the CEO shall immediately be disclosed to the Chair of the Board of Directors and the Chair of the committee exercising the function of the audit committee of the Board. Subject to any commitment made in connection with appointment to office or other requirement of law, a newly appointed Director or CEO shall proceed promptly with arrangements to divest the conflicting financial interest but should in any event conclude such divestiture within one year from the date of assuming office. The audit committee shall be responsible for initially reviewing all other such disclosures and making recommendations to the entire Board on what action, if any, should be taken. The entire Board, without the vote of any Director(s) involved, shall determine the appropriate action to be taken. No such review, recommendation, or determination is required, however, where an inadvertent violation is promptly remedied upon discovery and reported to the Chair of the Board of Directors and the Chair of the audit committee as provided herein.

6. Any waiver of this additional policy applicable to TVA Directors and the CEO may be made only by the Board, and will be disclosed promptly to the public, subject to the limitations on disclosure imposed by law.

----------------------------------------

Approved by the Board of Directors of the Tennessee Valley Authority

November 6, 2014

2

EX-31.1

EXHIBIT 31.1

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

I, William D. Johnson, certify that:

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

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and we have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	November 14, 2014	/s/ William D. Johnson
		William D. Johnson
		President and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

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

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

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

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and we have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	November 14, 2014	/s/ John M. Thomas, III
		John M. Thomas, III
		Executive Vice President and Chief Financial Officer (Principal Financial Officer)

EX-32.1

EXHIBIT 32.1

CERTIFICATION FURNISHED PURSUANT TO

SECURITIES EXCHANGE ACT RULE 13a-14(b)

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

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of the Tennessee Valley Authority (the “Company”) for the year ended September 30, 2014, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William D. Johnson, President and Chief Executive Officer of the Company, certify, for the purposes of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934, as amended, and Section 1350 of Chapter 63 of Title 18 of the United States Code, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ William D. Johnson

William D. Johnson

President and Chief Executive Officer

November 14, 2014

EX-32.2

EXHIBIT 32.2

CERTIFICATION FURNISHED PURSUANT TO

SECURITIES EXCHANGE ACT RULE 13a-14(b)

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

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of the Tennessee Valley Authority (the “Company”) for the year ended September 30, 2014, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John M. Thomas, III, Executive Vice President and Chief Financial Officer of the Company, certify, for the purposes of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934, as amended, and Section 1350 of Chapter 63 of Title 18 of the United States Code, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ John M. Thomas, III

John M. Thomas, III

Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

November 14, 2014

XML

Net Completed Plant Net Completed Plant (Tables)

12 Months Ended

Sep. 30, 2014

Net Completed Plant [Abstract]

Net Completed Plant

Net completed plant consisted of the following:

Net Completed Plant At September 30
	2014						2013
	Cost		Accumulated Depreciation		Net		Cost		Accumulated Depreciation		Net
Coal-fired	$	14,078	$	9,065	$	5,013	$	13,847	$	8,429	$	5,418
Gas and oil-fired	3,411		1,094		2,317		3,386		1,008		2,378
Nuclear	18,489		9,593		8,896		18,725		9,103		9,622
Transmission	6,519		2,683		3,836		6,300		2,562		3,738
Hydroelectric	2,547		889		1,658		2,392		892		1,500
Other electrical plant	1,550		885		665		1,452		792		660
Subtotal	46,594		24,209		22,385		46,102		22,786		23,316
Multipurpose dams	928		364		564		928		356		572
Other stewardship	42		16		26		43		15		28
Subtotal	970		380		590		971		371		600
Total	$	47,564	$	24,589	$	22,975	$	47,073	$	23,157	$	23,916

XML

Benefit Plans Other Postemployment Benefits (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Other Post-Employment Benefits
Discount rate	2.52%	2.64%	1.65%
Period expense	$ 34	$ (8)	$ 52
Postemployment benefits liability	520	535	597
Amount of Postemployment benefit actuarial gain (loss) from discount rate change		45
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent [Member]
Other Post-Employment Benefits
Postemployment benefits liability, noncurrent	472	486
Accounts payable and accrued liabilities
Other Post-Employment Benefits
Postemployment benefits liability, current	$ 48	$ 49

XML

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - General (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014 Customers People
Population of Service Area
Number of customers for whom unbilled revenues are estimated	6
Population of TVA's service area (number of people)	9,000,000
Possible amount of future payments to the Department of Energy under the blended low-enriched uranium program	$ 160
Estimated future payments attributable to blended low-enriched uranium fuel currently in use	101
Maximum original maturity	3 months
Recorded cost for emission allowances granted by the Environmental Protection Agency	0
BLEU fuel obligation	$ 16

XML

Proprietary Capital Proprietary Capital (Tables)

12 Months Ended

Sep. 30, 2014

Stockholders' Equity Note [Abstract]

Summary of Proprietary Capital Activity

The table below summarizes TVA's activities related to appropriated funds.

Summary of Proprietary Capital Activity At or for the years ended September 30
	2014						2013
Appropriation Investment	Power Program			Nonpower  Programs			Power Program			Nonpower  Programs
Balance at beginning of year	$	268		$	4,351		$	288		$	4,351
Return of power program appropriation investment	(10		)	—			(20		)	—
Balance at end of year	258			4,351			268			4,351
Retained Earnings
Balance at beginning of year	4,767			(3,742		)	4,492			(3,731		)
Net income (expense) for year	477			(8		)	282			(11		)
Return on power program appropriation investment	(4		)	—			(7		)	—
Balance at end of year	5,240			(3,750		)	4,767			(3,742		)
Net proprietary capital at September 30	$	5,498		$	601		$	5,035		$	609

XML

Unaudited Quarterly Financial Information Unaudited Quarterly Financial Information (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended								12 Months Ended
	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Quarterly Financial Information Disclosure [Abstract]
Operating revenues	$ 3,166	$ 2,651	$ 2,938	$ 2,382	$ 3,034	$ 2,602	$ 2,741	$ 2,579	$ 11,137	$ 10,956	$ 11,220
Operating expenses	2,569	2,453	2,362	2,164	2,276	2,324	2,380	2,523	9,548	9,503	9,920
Operating income	597	198	576	218	758	278	361	56	1,589	1,453	1,300
Net income (loss)	$ 322	$ (81)	$ 295	$ (67)	$ 474	$ (12)	$ 54	$ (245)	$ 469	$ 271	$ 60

XML

Debt and Other Obligations Debt and Other Obligations - General (Details) (USD $) In Billions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014 tests Types_of_bonds
Debt Instrument
Debt ceiling	$ 30.0
Number of types of bonds outstanding	2
Power bonds years to maturity - low end of range	1 year
Power bonds years to maturity - high end of range	50 years
Discount notes years to maturity - high end of range	1 year
Number of bond tests	2
Time period for meeting the bondholder protection test	5 years

XML

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Reclassificatons (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Reclassifications
Reclassification from Environmental cleanup costs-Kingston ash spill to Insurance recoveries	$ 47	$ 5

XML

Debt and Other Obligations Debt and Other Obligations - Lease/Leasebacks (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2003 Units	Sep. 30, 2014	Sep. 30, 2013
Lease/Leasebacks [Abstract]
Proceeds prior to 2004	$ 945
Leaseback transaction, number of units	24
Proceeds in 2003	389
CT and QTE outstanding leaseback obligation		$ 691	$ 761

XML

Benefit Plans Actuarial Assumptions (Details)	12 Months Ended					12 Months Ended			12 Months Ended						12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2010	Sep. 30, 2009	Sep. 30, 2014 Pension Benefits	Sep. 30, 2013 Pension Benefits	Sep. 30, 2012 Pension Benefits	Sep. 30, 2014 Other Post-retirement Benefits	Sep. 30, 2013 Other Post-retirement Benefits	Sep. 30, 2012 Other Post-retirement Benefits	Sep. 30, 2011 Other Post-retirement Benefits	Sep. 30, 2014 Minimum	Sep. 30, 2014 Maximum	Sep. 30, 2015 Scenario, Forecast [Member]	Sep. 30, 2020 Scenario, Forecast [Member]
Defined Benefit Plan Disclosure
Discount rate						4.45%	5.00%	4.00%	4.50%	5.05%	4.00%
Rate of compensation increase	5.70%	5.72%				5.70%	5.72%						3.50%	13.00%
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year									7.50%	8.00%	8.50%	8.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate									5.00%	5.00%	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate									2019	2019
Discount rate						5.00%	4.00%		5.05%	4.00%
Expected return on plan assets	7.25%	7.25%	7.25%			7.25%	7.25%								7.00%
Period during which actual company compensation experience study performed	5 years
Rate of compensation increase	5.72%	4.44%	4.43%			5.72%	4.44%
Minimum percentage increase in twelve-month average CPI-U necessary to receive COLA	1.00%
Number of years during which cost of living adjustment changed				4 years
Retirement age of eligibility for cost of living adjustment after January 1, 2010				60
Retirement age of eligibility for cost of living adjustment before January 1, 2010				55
Cost of living adjustment assumption	2.00%	1.60%			2.50%								1.00%	5.00%		2.50%
Rate of inflation															2.00%

XML

Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions (Tables)

12 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Summary of Derivative Instruments That Receive Hedge Accounting Treatment

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

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 1)  Amount of Mark-to-Market Gain (Loss) Recognized in 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	2014		2013
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	$	4	$	78

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2) Amount of Gain (Loss) Reclassified from OCI to Interest Expense For the years ended September 30
Derivatives in Cash Flow Hedging Relationship	2014		2013
Currency swaps	$	2	$	1

Note

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 $37 million of losses from AOCI to interest expense within the next twelve months to offset amounts anticipated to be recorded in interest expense related to exchange gain on the debt.

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment Amount of Gain (Loss) Recognized in Income on Derivatives(1) For the years ended September 30
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2014			2013
Interest rate swaps	To fix short-term debt variable rate to a fixed rate (interest rate risk)	MtM gains and losses are recorded as regulatory assets or liabilities until settlement, at which time the gains/losses are recognized in gain/loss on derivative contracts.(2)	$	—		$	—
Commodity contract derivatives	To protect against fluctuations in market prices of purchased coal or natural gas  (price risk)	MtM gains and losses are recorded as regulatory assets or liabilities. Realized gains and losses due to contract settlements are recognized in fuel expense as incurred.	(64		)	(11		)
Commodity derivatives under FTP	To protect against fluctuations in market prices of purchased commodities (price risk)	MtM 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.	(43		)	(126		)

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment Amount of Gain (Loss) Recognized in Income on Derivatives(1) For the years ended September 30
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2014			2013
Interest rate swaps	To fix short-term debt variable rate to a fixed rate (interest rate risk)	MtM gains and losses are recorded as regulatory assets or liabilities until settlement, at which time the gains/losses are recognized in gain/loss on derivative contracts.(2)	$	—		$	—
Commodity contract derivatives	To protect against fluctuations in market prices of purchased coal or natural gas  (price risk)	MtM gains and losses are recorded as regulatory assets or liabilities. Realized gains and losses due to contract settlements are recognized in fuel expense as incurred.	(64		)	(11		)
Commodity derivatives under FTP	To protect against fluctuations in market prices of purchased commodities (price risk)	MtM 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.	(43		)	(126		)

Notes

(1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there was no related gain (loss) recognized in income for these unrealized gains (losses) for the years ended 2014 and 2013.

(2) Generally, TVA maintains a level of outstanding discount notes equal to or greater than the notional amount of the interest rate swaps. However, in September 2014 TVA issued long-term Bonds in anticipation of the maturity of other long-term debt, and used the proceeds to pay down discount notes, which caused the balance of discount notes outstanding at September 30, 2014, to fall below the notional amount of the interest rate swaps. There is no impact on the statements of operations due to the use of regulatory accounting for these items.

Mark-to-Market Value of TVA Derivatives

Mark-to-Market Values of TVA Derivatives At September 30
	2014				2013
Derivatives that Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Currency swaps
£200 million Sterling	$	(15	)	Other long-term liabilities	$	(15	)	Other long-term liabilities
£250 million Sterling	56			Other long-term assets	51			Other long-term assets
£150 million Sterling	8			Other long-term assets	10			Other long-term assets
Derivatives that Do Not Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Interest rate swaps
$1.0 billion notional	(987		)	Other long-term liabilities	(886		)	Other long-term liabilities
$476 million notional	(349		)	Other long-term liabilities	(300		)	Other long-term liabilities
$42 million notional	(12		)	Other long-term liabilities	(13		)	Other long-term liabilities
Commodity contract derivatives	(96		)	Other current assets $1; Other long-term liabilities $(17); Accounts payable and accrued liabilities $(80)	(141		)	Other long-term assets $1; Other current assets $2; Other long-term liabilities $(35); Accounts payable and accrued liabilities $(109)
FTP
Derivatives under FTP(1)	(103		)	Other current assets $(69); Other long-term liabilities $(14); Accounts payable and accrued liabilities $(20)	(166		)	Other current assets $(97); Other long-term liabilities $(36); Accounts payable and accrued liabilities $(33)

Note

(1)   Fair values of certain derivatives under the FTP that were in net liability positions totaling $69 million and $100 million at September 30, 2014 and September 30, 2013, respectively, are recorded in TVA's margin cash accounts in Other current assets. These derivatives are transacted with futures commission merchants, and cash deposits have been posted to the margin cash accounts held with each futures commission merchant to offset the net liability positions in full.

Currency Swaps Outstanding

TVA had the following currency swaps outstanding at September 30, 2014:

Currency Swaps Outstanding At September 30, 2014
Effective Date of Currency Swap Contract	Associated TVA Bond Issues Currency Exposure	Expiration Date of Swap	Overall Effective Cost to TVA
1999	£200 million	2021	5.81%
2001	£250 million	2032	6.59%
2003	£150 million	2043	4.96%

Commodity Contract Derivatives

Commodity Contract Derivatives At September 30
	2014					2013
	Number ofContracts	Notional Amount	Fair Value (MtM)			Number of Contracts	Notional Amount	Fair Value (MtM)
Coal contract derivatives	24	31 million tons	$	(86	)	19	43 million tons	$	(140	)
Natural gas contract derivatives	46	62 million mmBtu	$	(10	)	13	39 million mmBtu	$	(1	)

Derivatives Under Financial Trading Program

Derivatives under Financial Trading Program At September 30
	2014				2013
	Notional Amount	Fair Value (MtM) (in millions)			Notional Amount	Fair Value (MtM) (in millions)
Natural gas (in mmBtu)
Futures contracts	—	$	—		—	$	—
Swap contracts	102,227,500	(103		)	152,922,500	(169		)
Option contracts	—	—			—	—
Natural gas financial positions	102,227,500	$	(103	)	152,922,500	$	(169	)
Fuel oil/crude oil (in barrels)
Futures contracts	—	$	—		—	$	—
Swap contracts	—	—			1,205,000	3
Option contracts	—	—			—	—
Fuel oil/crude oil financial positions	—	$	—		1,205,000	$	3

Note

Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the broker or other counterparty.  Notional amounts disclosed represent the net absolute value of contractual amounts.

FTP Unrealized Gains (Losses)

Financial Trading Program Unrealized Gains (Losses) At September 30
FTP unrealized gains (losses) deferred as regulatory liabilities (assets)	2014			2013
Natural gas	$	(103	)	$	(169	)
Fuel oil/crude oil	—			3
Coal	—			—

FTP Realized Gains (Losses)

Financial Trading Program Realized Gains (Losses) For the years ended September 30
Decrease (increase) in fuel expense	2014			2013
Natural gas	$	(34	)	$	(78	)
Fuel oil/crude oil	2			4
Coal	—			(1		)

Financial Trading Program Realized Gains (Losses) For the years ended September 30
Decrease (increase) in purchased power expense	2014			2013
Natural gas	$	(11	)	$	(51	)

Offsetting Assets and Liabilities [Table Text Block]

The amounts of TVA's derivative instruments as reported in the Consolidated Balance Sheets as of September 30, 2014, and September 30, 2013, are shown in the table below.

	As of September 30, 2014
	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
Currency swaps	$	64		$	(64	)	$	—
Commodity derivatives under FTP	51			(51		)	—
Total derivatives subject to master netting or similar arrangement	115			(115		)	—
Total derivatives not subject to master netting or similar arrangement	1			—			1
Total	$	116		$	(115	)	$	1
Liabilities
Currency swap (3)	$	(15	)	$	—		$	(15	)
Interest rate swaps (3)	(1,348		)	—			(1,348		)
Commodity derivatives under FTP	(154		)	120			(34		)
Total derivatives subject to master netting or similar arrangement	(1,517		)	120			(1,397		)
Total derivatives not subject to master netting or similar arrangement	(97		)	—			(97		)
Total	$	(1,614	)	$	120		$	(1,494	)
	As of September 30, 2013
	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
Currency swaps	$	61		$	(33	)	$	28
Commodity derivatives under FTP	101			(98		)	3
Total derivatives subject to master netting or similar arrangement	162			(131		)	31
Total derivatives not subject to master netting or similar arrangement	3			—			3
Total	$	165		$	(131	)	$	34
Liabilities
Currency swap (3)	$	(15	)	$	—		$	(15	)
Interest rate swaps (3)	(1,199		)	—			(1,199		)
Commodity derivatives under FTP	(267		)	198			(69		)
Total derivatives subject to master netting or similar arrangement	(1,481		)	198			(1,283		)
Total derivatives not subject to master netting or similar arrangement	(144		)	—			(144		)
Total	$	(1,625	)	$	198		$	(1,427	)

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 which are not offset in the balance sheets.

(3) Letters of credit of approximately $1.0 billion and $800 million were posted as collateral at September 30, 2014 and September 30, 2013, 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.

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Asset Retirement Obligations Asset Retirement Obligations (Policies)

12 Months Ended

Sep. 30, 2014

Asset Retirement Obligation [Abstract]

Asset Retirement Obligations, Policy [Policy Text Block]

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 reclamation.  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.  Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset.  See Note 8 — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs andNote 12.

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. Prior to June 30, 2014, TVA based its decommissioning cost estimates on cost elements prescribed by the NRC to dismantle and decommission the radioactive portion of each site with the assumption that decommissioning would occur within the first seven years after plant shut down, which approximates the DECON method of decommissioning. The DECON method requires that radioactive contamination is 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. On June 30, 2014, TVA recorded a change in estimate based on site-specific decommissioning cost studies. Additionally, TVA determined it appropriate to reflect an increase in the probability that certain of its nuclear operating licenses will be extended and that there is a probability that it will be able to delay ultimate decommissioning activities under a SAFSTOR method of decommissioning. 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. As such, TVA ascribed probabilities to both the SAFSTOR and DECON methods of decommissioning in order to estimate its decommissioning obligation. Decommissioning cost studies will be updated for each of TVA’s nuclear units at least every five years.

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Accumulated Other Comprehensive Income (Loss) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Equity [Abstract]
Reclassification on cash flow hedges from AOCI to interest expense	$ 2	$ 1	$ 35

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Commitments and Contingencies Commitments and Contingencies - Contingencies (Details) (USD $)	12 Months Ended
	Sep. 30, 2014 reactors Procedures Insurance_layers Units Sites	Sep. 30, 2013	Sep. 30, 2012
Contingencies
Nuclear liability insurance	$ 375,000,000
Assessment from licensees for each licensed reactor	127,000,000
Number of licensed reactors in US	104
Nuclear accident assessment limitation per year per unit	19,000,000
Number of licensed nuclear units	6
Maximum assessment per nuclear incident	764,000,000
Maximum payment required per accident in any one year	114,000,000
Total amount of protection available	13,000,000,000
Surcharge for legal expenses	5.00%
The U.S. Congress is required to take action if these layes are exhausted	2
Amount of property, decommissioning, and decontamination insurance carried	5,100,000,000
Amount of insurance available for loss at any one site	2,100,000,000
Number of sites	1
Maximum amount of retrospective premiums	120,000,000
Maximum idemnity if a covered accident tasks or keeps a nuclear unit offline	490,000,000
Maximum amount of retrospective premiums	35,000,000
Number of procedures for determining estimates for the costs of nuclear decommissioning	2
Amount spent to reduce emissions since 1970	5,900,000,000
Amount spent to reduce emissions	378,000,000	197,000,000	55,000,000
Possible additional future costs for compliance with Clean Air Act requirements	900,000,000
Amount of settlement for potential liability related to soil cleanup	300,000
Amount of settlement for potential liability related to EPA study of site	8,000
Remaining natural resource damages are less than	1,000,000
Estimated liability for cleanup and similar environmental work on a non-discounted basis	15,000,000	15,000,000
Expected increase (decrease) in operation and maintenance expense	(500,000,000)
Restructuring and Related Cost, Number of Positions Eliminated	2,000
Severance cost liability	45,000,000	0
Nuclear
Contingencies
Future estimated decommissioning cost	2,100,000,000
Non-nuclear
Contingencies
Future estimated decommissioning cost	$ 1,100,000,000

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Debt and Other Obligations Debt and Other Obligations - Put and Call Options (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014 Bond_issues PARRS_issues
Debt Instrument
Amount of redeemable bond issues outstanding	$ 515
Call price	100.00%
Bond issues with survivor's option	15
Bonds outstanding with survivor's option	375
Number of issues of Putable Automatic Rate Reset Securities outstanding	2
Fixed-rate period for coupon rate reset on PARRS	5 years
Average time period	5 days
PARRS 1998 Series D Bond
Debt Instrument
Amount of redeemable bond issues outstanding	324
Debt Instrument, Basis Point Spread on Variable Rate	94
Number of rate resets	6
PARRS interest rate prior to rate reset	6.75%
PARRS interest rate after rate reset	3.83%
Amount of bonds redeemed	251
PARRS 1999 Series A Bond
Debt Instrument
Amount of redeemable bond issues outstanding	270
Debt Instrument, Basis Point Spread on Variable Rate	84
Number of rate resets	5
PARRS interest rate prior to rate reset	6.50%
PARRS interest rate after rate reset	3.955%
Amount of bonds redeemed	$ 255

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Fair Value Measurements Fair Value Measurements - Nonperformance Risk (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014
Nonperformance Risk
Derivative credit valuation adjustment, assets	$ 1
Derivative credit valuation adjustment, liabilities	$ 1

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Property, Plant, and Equipment, and Depreciation (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2014 Nuclear	Sep. 30, 2013 Nuclear	Sep. 30, 2012 Nuclear	Sep. 30, 2014 Coal-Fired	Sep. 30, 2013 Coal-Fired	Sep. 30, 2012 Coal-Fired	Sep. 30, 2014 Hydroelectric	Sep. 30, 2013 Hydroelectric	Sep. 30, 2012 Hydroelectric	Sep. 30, 2014 Gas and Oil-Fired	Sep. 30, 2013 Gas and Oil-Fired	Sep. 30, 2012 Gas and Oil-Fired	Sep. 30, 2014 Transmission	Sep. 30, 2013 Transmission	Sep. 30, 2012 Transmission	Sep. 30, 2014 Other	Sep. 30, 2013 Other	Sep. 30, 2012 Other	Sep. 30, 2014 Electricity Generation Plant, Non-Nuclear	Sep. 30, 2013 Electricity Generation Plant, Non-Nuclear	Sep. 30, 2014 Fuel Fabrication and Blending Facilities	Sep. 30, 2013 Fuel Fabrication and Blending Facilities	Jun. 30, 2011 Environmental Agreements Units
Property, Plant, and Equipment, and Depreciation
Depreciation	$ 1,600,000,000	$ 1,400,000,000	$ 1,700,000,000
Composite depreciation rate for completed plant	3.42%	3.12%	3.78%	2.90%	2.86%	2.71%	4.37%	3.47%	5.65%	1.44%	1.30%	1.35%	3.23%	3.21%	3.67%	2.76%	2.76%	2.99%	8.40%	8.14%	8.10%
Number of units to be idled																										18
Accelerated depreciation	206,000,000	49,000,000
Capital leases	102,000,000	47,000,000																				102,000,000	42,000,000	0	5,000,000
Allowance for funds used during construction and nuclear fuel expenditures	175,000,000	168,000,000
AFUDC minimum total project cost	1,000,000,000
Minimum construction period.	3 years
Accumulated balance of qualifying projects	3,300,000,000
Capitalized software amortization period	5 years
Unamortized computer software costs	22,000,000	5,000,000
Amortization expense of capitalized computer software costs	$ 31,000,000	$ 31,000,000	$ 31,000,000

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Benefit Plans Fair Value Measurements Using Significant Unobservable Inputs (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2012
Defined Benefit Plan Disclosure
Fair value of gross plan assets	$ 7,600	[1],[2]	$ 7,363
Fair Value, Inputs, Level 3
Defined Benefit Plan Disclosure
Fair value of gross plan assets	648		656	633
Net realized/unrealized gains and losses	50		45
Purchases, sales, issuances, and settlements	(53)		(21)
Transfers in and/or out of Level 3	$ (5)		$ (1)

[1] Excludes approximately $65 million in net payables associated with security purchases and sales and various other payables.

[2] Excludes a $3 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

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Debt and Other Obligations Debt and Other Obligations - Maturities Due (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Debt Instrument
2015	$ 1,064
2016	65
2017	1,590
2018	1,718
2019	1,070
Thereafter	18,829
Total	24,336
Foreign currency exchange loss	44	43
Unamortized discount, premiums and other	89	85
Short-term debt, net of discounts	$ 596	$ 2,432

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Counterparty Credit Risk (Details)	Sep. 30, 2014 Customers	Sep. 30, 2013 Customers
Derivative
Number of active future commission merchants	2
Credit of Customers
Derivative
Number of customers that represent the percent of outstanding accounts receivable	3	3
Percent of total outstanding accounts receivables by customers	27.00%	27.00%
Power Purchase Agreement
Derivative
Megawatts in a power purchase agreement that expires on March 31, 2032	440

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivative Instruments That Do Not Receive Hedge Accounting Treatment (Details) (USD $)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013
Derivative
Change in Unrealized gains (losses) on Interest Rate Derivatives	$ (149,000,000)		$ 524,000,000
Amount of gain (loss) recognized in income on derivatives	(57,000,000)
Unrealized gains/losses on derivatives	0		0
FTP transaction limit	130,000,000
Maximum hedge volume	75.00%
Market value limitation of outstanding construction materials hedging transactions	100,000,000
Portfolio value at risk limit for foreign currency transactions	5,000,000
Interest Rate Swap
Derivative
Amount of gain (loss) recognized in income on derivatives	0	[1]	0	[1]
Commodity Contract Derivatives
Derivative
Amount of gain (loss) recognized in income on derivatives	(64,000,000)		(11,000,000)
Fair value	(96,000,000)		(141,000,000)
Commodity Derivatives Under Financial Trading Program
Derivative
Amount of gain (loss) recognized in income on derivatives	(43,000,000)		(126,000,000)
Fair value	(103,000,000)	[2]	(166,000,000)	[2]
Coal Contract Derivatives
Derivative
Number of contracts	24		19
Notional amount	31,000,000		43,000,000
Fair value	(86,000,000)		(140,000,000)
Natural Gas
Derivative
Number of contracts	46		13
Notional amount	62,000,000		39,000,000
Fair value	(10,000,000)		(1,000,000)
Maximum | Coal Contract Derivatives
Derivative
Derivative, Term of Contract	3 years
Maximum | Natural Gas
Derivative
Derivative, Term of Contract	2 years
Coal Contract Derivatives
Derivative
Unrealized gains/losses on derivatives	0		0
Fair value	$ 0		$ 0

[1] Generally, TVA maintains a level of outstanding discount notes equal to or greater than the notional amount of the interest rate swaps. However, in September 2014 TVA issued long-term Bonds in anticipation of the maturity of other long-term debt, and used the proceeds to pay down discount notes, which caused the balance of discount notes outstanding at September 30, 2014, to fall below the notional amount of the interest rate swaps. There is no impact on the statements of operations due to the use of regulatory accounting for these items.

[2] Fair values of certain derivatives under the FTP that were in net liability positions totaling $69 million and $100 million at September 30, 2014 and September 30, 2013, respectively, are recorded in TVA's margin cash accounts in Other current assets. These derivatives are transacted with futures commission merchants, and cash deposits have been posted to the margin cash accounts held with each futures commission merchant to offset the net liability positions in full.

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Offsetting of Derivative Assets and Liabilities (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets, subject to master netting or similar arrangements	$ 115	$ 162
Gross Amounts Offset in the Balance Sheet	(115)	(131)	[1]
Net Amounts of Assets Presented in the Balance Sheet	1	34	[2]
Total derivatives not subject to master netting or similar arrangement	1	3	[2]
Total Gross Amounts of Recognized Assets	116	165
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities, Subject to Master Netting or Similar Arrangements	(1,517)	(1,481)
Gross Amounts Offset in the Balance Sheet	120	198	[1]
Net Amounts of Liabilities Presented in the Balance Sheet	(1,494)	(1,427)	[2]
Total derivatives not subject to master netting or similar arrangement	(97)	(144)	[2]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	1,614	1,625
Letter of Credit
Offsetting Liabilities [Line Items]
Amount of letters of credit outstanding	1,000	800
Currency Swap
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets, subject to master netting or similar arrangements	64	61
Gross Amounts Offset in the Balance Sheet	(64)	(33)	[1]
Net Amounts of Assets Presented in the Balance Sheet	0	28	[2]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities, Subject to Master Netting or Similar Arrangements	(15)	(15)	[3]
Gross Amounts Offset in the Balance Sheet	0	0	[1],[3]
Net Amounts of Liabilities Presented in the Balance Sheet	(15)	(15)	[2],[3]
Interest Rate Contract
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities, Subject to Master Netting or Similar Arrangements	(1,348)	(1,199)	[3]
Gross Amounts Offset in the Balance Sheet	0	0	[1],[3]
Net Amounts of Liabilities Presented in the Balance Sheet	(1,348)	(1,199)	[2],[3]
Commodity derivatives under FTP
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets, subject to master netting or similar arrangements	51	101
Gross Amounts Offset in the Balance Sheet	(51)	(98)	[1]
Net Amounts of Assets Presented in the Balance Sheet	0	3	[2]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities, Subject to Master Netting or Similar Arrangements	(154)	(267)
Gross Amounts Offset in the Balance Sheet	120	198	[1]
Net Amounts of Liabilities Presented in the Balance Sheet	(34)	(69)	[2]
Total derivatives subject to master netting or similar arrangement [Member]
Offsetting Assets [Line Items]
Net Amounts of Assets Presented in the Balance Sheet	0	31	[2]
Offsetting Liabilities [Line Items]
Net Amounts of Liabilities Presented in the Balance Sheet	$ (1,397)	$ (1,283)	[2]

[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 which are not offset in the balance sheets.

[3] Letters of credit of approximately $1.0 billion and $800 million were posted as collateral at September 30, 2014 and September 30, 2013, 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.

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Debt and Other Obligations Debt and Other Obligations - Credit Facility Agreements (Details) (USD $)	Sep. 30, 2014	Sep. 30, 2013
Credit Facility Agreements
Current borrowing capacity	$ 150,000,000
Line of Credit
Credit Facility Agreements
Current borrowing capacity	150,000,000
Credit facility agreements borrowings outstanding	0
Amount of letters of credit outstanding	1,000,000,000	800,000,000
Revolving Credit Facilities
Credit Facility Agreements
Current borrowing capacity	2,500,000,000
Credit facility agreements borrowings outstanding	0	0
Number of revolving credit facilities	3
Revolving credit facility 1	1,000,000,000
Revolving credit facility 2	1,000,000,000
Revolving credit facility 3	$ 500,000,000

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Debt and Other Obligations Debt and Other Obligations - Secured Debt of VIEs (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Aug. 09, 2013	Aug. 09, 2013 SCCG	Jan. 17, 2012 JSCCG	Jan. 17, 2012 Holdco
Debt Instrument
Face Amount				$ 360	$ 900	$ 100
Membership interests of VIE subject to mandatory redemption	50	50	40
Interest rate				3.846%	4.626%	7.10%
Holdco balloon payment upon maturity						10
Long-term debt of variable interest entities (including current maturities)	$ 1,425	$ 1,386

XML

Supplemental Cash Flow Information

12 Months Ended

Sep. 30, 2014

Supplemental Cash Flow Information [Abstract]

Supplemental Cash Flow Information

Supplemental Cash Flow Information

Interest paid was $1.3 billion, $1.3 billion, and $1.4 billion in 2014, 2013, and 2012, respectively. These amounts differ from interest expense due to the timing of payments and interest capitalized of $175 million in 2014, $168 million in 2013, and $171 million in 2012 as a part of major capital expenditures. 

Construction in progress and Nuclear fuel expenditures included in Accounts payable and accrued liabilities at September 30, 2014, 2013, and 2012 were $391 million, $270 million, and $204 million, respectively, and are excluded from the Statements of Consolidated Cash Flows for the years ended 2014, 2013, and 2012 as non-cash investing activities.  In November 2013, in accordance with the regulated operations property, plant and equipment accounting guidance, the TVA Board approved the treatment of all amounts currently included in Construction in progress related to Bellefonte as a regulatory asset. Bellefonte amounts included in Construction expenditures for 2013 and 2012 were $162 million and $212 million, respectively.

TVA had non-cash activity related to financing activities on the 2014, 2013, and 2012 Consolidated Statements of Cash Flows related to capital leases of $70 million, $20 million, and $6 million, respectively.

Cash flows from futures contracts, forward contracts, option contracts, and swap contracts that are accounted for as hedges are classified in the same category as the item being hedged or on a basis consistent with the nature of the instrument.

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Benefit Plans Benefit Plans (Tables)

12 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

Obligations and Funded Status

The changes in plan obligations, assets, and funded status for the years ended September 30, 2014 and 2013, were as follows:

Obligations and Funded Status For the years ended September 30
	Pension Benefits						Other Post-Retirement Benefits
	2014			2013			2014			2013
Change in benefit obligation
Benefit obligation at beginning of year	$	11,471		$	11,995		$	656		$	811
Service cost	130			154			18			24
Interest cost	558			468			32			31
Plan participants’ contributions	28			29			—			—
Collections(1)	—			—			93			79
Amendments	2			4			—			—
Actuarial loss (gain)	722			(549		)	(21		)	(163		)
Net transfers from variable fund/401(k) plan	13			4			—			—
Expenses paid	(6		)	(6		)	—			—
Benefits paid	(653		)	(628		)	(126		)	(126		)
Benefit obligation at end of year	12,265			11,471			652			656
Change in plan assets
Fair value of net plan assets at beginning of year	7,221			7,029			—			—
Actual return on plan assets	648			787			—			—
Plan participants’ contributions	28			29			—			—
Collections(1)	—			—			93			79
Net transfers from variable fund/401(k) plan	13			4			—			—
Employer contributions(2)	256			6			33			47
Expenses paid	(6		)	(6		)	—			—
Benefits paid	(653		)	(628		)	(126		)	(126		)
Fair value of net plan assets at end of year	7,507			7,221			—			—
Funded status	$	(4,758	)	$	(4,250	)	$	(652	)	$	(656	)

Amounts Recognized on TVA's Consolidated Balance Sheets

Amounts related to these benefit plans recognized on TVA's consolidated balance sheets consist of regulatory assets that have not been recognized as components of net periodic benefit cost at September 30, 2014 and 2013, 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
	2014			2013			2014			2013
Regulatory assets	$	4,157		$	3,910		$	140		$	166
Accounts payable and accrued liabilities	(5		)	(5		)	(38		)	(39		)
Pension and post-retirement benefit obligations(1)	(4,753		)	(4,245		)	(614		)	(617		)

Note

(1) Table above excludes $472 million and $486 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, 2014 and 2013, respectively.

Postretirement Benefit Costs Deferred as Regulatory Assets

Unrecognized amounts included in regulatory assets yet to be recognized as components of accrued benefit cost at September 30 consisted of:

Post-retirement Benefit Costs Deferred as Regulatory Assets At September 30
	Pension Benefits						Other Post-Retirement Benefits
	2014			2013			2014			2013
Unrecognized prior service cost (credit)	$	(180	)	$	(203	)	$	(39	)	$	(45	)
Unrecognized net loss	4,337			4,113			179			211
Total regulatory assets	$	4,157		$	3,910		$	140		$	166

Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets

The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for the pension plan at September 30, 2014, and 2013, were as follows:

Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets At September 30
	2014		2013
Projected benefit obligation	$	12,265	$	11,471
Accumulated benefit obligation	12,039		11,216
Fair value of net plan assets	7,507		7,221

Components of Net Periodic Benefit Cost

The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the years ended September 30, 2014, and 2013, were as follows:

Components of Net Periodic Benefit Cost For the years ended September 30
	Pension Benefits									Other Post-Retirement Benefits
	2014			2013			2012			2014			2013			2012
Service cost	$	130		$	154		$	139		$	18		$	24		$	19
Interest cost	558			468			490			32			31			35
Expected return on plan assets	(435		)	(428		)	(437		)	—			—			—
Amortization of prior service credit	(21		)	(22		)	(23		)	(6		)	(6		)	(6		)
Recognized net actuarial loss	285			377			361			11			25			29
Total net periodic benefit cost recognized	$	517		$	549		$	530		$	55		$	74		$	77

Expected Amortization of Regulatory Assets in Next Fiscal Year

The amounts in the regulatory asset that are expected to be recognized as components of net periodic benefit cost during the next fiscal year are as follows:

Expected Amortization of Regulatory Assets in 2015 At September 30, 2014
	Pension Benefits			Other Post-Retirement Benefits			Total
Prior service cost (credit)	$	(21	)	$	(6	)	$	(27	)
Net actuarial loss	277			8			285

Actuarial Assumptions

TVA’s reported costs of providing the plan benefits are impacted by numerous factors including the provisions of the plans, changing employee demographics, and various assumptions, the most significant of which are noted below.

Actuarial Assumptions At September 30
	Pension Benefits				Other Post-Retirement Benefits
	2014		2013		2014		2013
Assumptions utilized to determine benefit obligations at September 30
Discount rate	4.45	%	5.00	%	4.50	%	5.05	%
Rate of compensation increase	5.70	%	5.72	%	N/A		N/A
Initial health care cost trend rate	N/A		N/A		7.50	%	8.00	%
Ultimate health care cost trend rate	N/A		N/A		5.00	%	5.00	%
Ultimate trend rate is reached in year beginning	N/A		N/A		2019		2019
Assumptions utilized to determine net periodic benefit cost for the years ended September 30
Discount rate	5.00	%	4.00	%	5.05	%	4.00	%
Expected return on plan assets	7.25	%	7.25	%	N/A		N/A
Rate of compensation increase	5.72	%	4.44	%	N/A		N/A
Initial health care cost trend rate	N/A		N/A		8.00	%	8.50	%
Ultimate health care cost trend rate	N/A		N/A		5.00	%	5.00	%
Ultimate trend rate is reached in year beginning	N/A		N/A		2019		2019

Sensitivity to Certain Changes in Pension Assumptions

The following chart reflects the sensitivity of pension cost to changes in certain actuarial assumptions:

Sensitivity to Certain Changes in Pension Assumptions At September 30, 2014
Actuarial Assumption	Change in Assumption		Impact on 2014 Pension Cost		Impact on 2014 Projected Benefit Obligation
Discount rate	(0.25	)	$	18	$	369
Rate of return on plan assets	(0.25	)	15		N/A

Sensitivity to Changes in Assumed Health Care Cost Trend Rates

The following chart reflects the sensitivity of post-retirement benefit cost to changes in the health care trend rate:

Sensitivity to Changes in Assumed Health Care Cost Trend Rates At September 30, 2014
	1% Increase		1% Decrease
Effect on total of service and interest cost components for the year	$	7	$	(7	)
Effect on end-of-year accumulated post-retirement benefit obligation	89		(93		)

Asset Holdings and Fair Value Measurements

Asset Holdings of TVARS At September 30
			Plan Assets at September 30
Asset Category	Target Allocation		2014		2013
Global equity	32	%	43	%	48	%
Private equity	10	%	5	%	6	%
Low volatility global public equity	5	%	1	%	—	%
Cash	2	%	2	%	2	%
Core fixed income	5	%	5	%	5	%
Long-term core fixed income	5	%	5	%	4	%
Investment grade credit	6	%	6	%	6	%
International emerging markets fixed income	5	%	5	%	—	%
High yield fixed income	5	%	6	%	10	%
Global TIPS	5	%	5	%	7	%
Private real assets	10	%	7	%	7	%
Commodities	5	%	4	%	—	%
MLPs	5	%	6	%	5	%
Total	100	%	100	%	100	%

Fair Value Measurements

The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2014:

TVA Retirement System At September 30, 2014
	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	$	1,669	$	1,668	$	—	$	1
Preferred securities	37		5		32		—
Debt securities
Corporate debt securities	1,326		—		1,304		22
Residential mortgage-backed securities	204		—		201		3
Debt securities issued by U.S. Treasury and other U.S. government agencies	93		93		—		—
Debt securities issued by foreign governments	225		—		218		7
Asset-backed securities	176		—		147		29
Debt securities issued by state/local governments	30		—		29		1
Commercial mortgage-backed securities	23		—		20		3
Commingled Funds
Equity	1,106		—		1,106		—
Debt	661		—		661		—
Commodity	332		—		332		—
Blended	228		—		228		—
Institutional mutual funds	28		28		—		—
Cash equivalents and other short-term investments	464		—		464		—
Certificates of deposit	19		—		19		—
Private equity funds	481		—		—		481
Private real estate funds	435		—		334		101
Treasury bills, U.S. Government notes, and securities held as futures and other derivative collateral	35		10		25		—
Securities lending commingled funds	2		—		2		—
Derivatives
Purchased options	18		—		18		—
Foreign currency forward receivable	8		—		8		—
Total Assets	$	7,600	$	1,804	$	5,148	$	648
Liabilities
Derivatives
Futures	11		$	11	$	—	$	—
Foreign currency forward payable	8		—		8		—
Written option obligations	7		—		7		—
Total Liabilities	$	26	$	11	$	15	$	—

Notes

(1) Excludes approximately $65 million in net payables associated with security purchases and sales and various other payables.

(2) Excludes a $2 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2013:

TVA Retirement System At September 30, 2013
	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	$	1,689	$	1,686	$	—	$	3
Preferred securities	22		17		—		5
Debt securities
Corporate debt securities	1,352		—		1,334		18
Residential mortgage-backed securities	355		—		352		3
Debt securities issued by U.S. Treasury and other U.S. government agencies	113		113		—		—
Debt securities issued by foreign governments	31		—		30		1
Asset-backed securities	120		—		110		10
Debt securities issued by state/local governments	36		—		36		—
Commercial mortgage-backed securities	21		—		18		3
Commingled Funds
Equity	1,182		—		1,182		—
Debt	786		—		786		—
Blended	263		—		263		—
Institutional mutual funds	26		26		—		—
Cash equivalents and other short-term investments	395		1		394		—
Private equity funds	528		—		—		528
Private real estate funds	382		—		297		85
Treasury bills, U.S. Government notes, and securities held as futures and other derivative collateral	39		8		31		—
Securities lending commingled funds	3		—		3		—
Derivatives
Foreign currency forward receivable	6		—		6		—
Purchased options	6		—		6		—
Credit default swaps	4		—		4		—
Written option obligations	4		4		—		—
Total Assets	$	7,363	$	1,855	$	4,852	$	656
Liabilities
Derivatives
Foreign currency forward payable	$	6	$	—	$	6	$	—
Credit default swaps	1		—		1		—
Written option obligations	1		—		1		—
Total Liabilities	$	8	$	—	$	8	$	—

Notes

(1) Excludes approximately $131 million in net payables associated with security purchases and sales and various other payables.

(2) Excludes a $3 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

Fair Value Measurements Using Significant Unobservable Inputs

The following table provides a reconciliation of beginning and ending balances of pension plan assets measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3):

Fair Value Measurements Using Significant Unobservable Inputs
	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Balance at October 1, 2012	$	633
Net realized/unrealized gains (losses)	45
Purchases, sales, issuances, and settlements (net)	(21		)
Transfers in and/or out of Level 3	(1		)
Balance at September 30, 2013	656
Net realized/unrealized gains (losses)	50
Purchases, sales, issuances, and settlements (net)	(53		)
Transfers in and/or out of Level 3	(5		)
Balance at September 30, 2014	$	648

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, 2014
	Pension Benefits		Other Post-Retirement Benefits
2015	$	712	$	39
2016	715		40
2017	720		41
2018	724		41
2019	731		41
2020 - 2024	3,759		186

XML

Variable Interest Entities Variable Interest Entities (Tables)

12 Months Ended

Sep. 30, 2014

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Variable Interest Entities

The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG as of September 30, 2014 and 2013, as reflected in the Consolidated Balance Sheets, are as follows:

Summary of Impact of VIEs on Consolidated Balance Sheets At September 30
	2014		2013
Current liabilities of VIE
Accrued interest of VIE	$	12	$	12
Current portion of membership interests of VIE subject to mandatory redemption	2		2
Current maturities of long-term debt of VIE	32		30
Total current liabilities of VIE	46		44
Other liabilities of VIE
Membership interests of VIE subject to mandatory redemption	37		38
Long-term debt of VIE, net
Long-term debt of VIE	1,279		1,311
Total liabilities of VIE	$	1,362	$	1,393

XML

Debt and Other Obligations Debt and Other Obligations - Debt Outstanding (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014 Electronotes		Sep. 30, 2013
Short-term debt
Short-term debt, net of discounts	$ 596		$ 2,432
Current maturities of long-term debt of variable interest entities	32		30
Current maturities of power bonds	1,032		32
Total current debt outstanding, net	1,660		2,494
Long-term debt
Unamortized discount, premiums and other	(89)		(85)
Long-term debt of variable interest entities	1,279		1,311
Total long-term debt, net	23,227		23,626
Long-term power bonds	22,037	[1]	22,400	[1]
Long-term Debt, net	21,948		22,315
Current maturities of power bonds	1,032		32
Foreign currency exchange loss	44		43
Number of issues with partial maturities	1
Electronotes
Long-term debt
Long-term Debt, net	387	[2]	723	[2]
Maturity date - earliest	May 15, 2020
Maturity date - latest	Feb. 15, 2043
Coupon rate - minimum	2.375%
Coupon rate - maximum	4.375%
Call date - earliest	Feb. 15, 2015
Call date - latest	Feb. 15, 2018
880591DY5
Debt Instrument
Maturity	Jun. 15, 2015
Coupon rate	4.375%
Long-term debt
Long-term Debt, net	0		1,000
880591EE8
Debt Instrument
Maturity	Nov. 15, 2015
Coupon rate	2.25%
Long-term debt
Long-term Debt, net	2	[3]	4	[3]
880591DS8
Debt Instrument
Maturity	Dec. 15, 2016
Coupon rate	4.875%
Long-term debt
Long-term Debt, net	524		524
880591EA6
Debt Instrument
Maturity	Jul. 18, 2017
Coupon rate	5.50%
Long-term debt
Long-term Debt, net	1,000		1,000
880591CU4
Debt Instrument
Maturity	Dec. 15, 2017
Coupon rate	6.25%
Long-term debt
Long-term Debt, net	650		650
880591EC2
Debt Instrument
Maturity	Apr. 01, 2018
Coupon rate	4.50%
Long-term debt
Long-term Debt, net	1,000		1,000
880591EQ1
Debt Instrument
Maturity	Oct. 15, 2018
Coupon rate	1.75%
Long-term debt
Long-term Debt, net	1,000		1,000
880591EL2
Debt Instrument
Maturity	Feb. 15, 2021
Coupon rate	3.875%
Long-term debt
Long-term Debt, net	1,500		1,500
880591DC3
Debt Instrument
Maturity	Jun. 07, 2021
Coupon rate	5.805%
Long-term debt
Long-term Debt, net	324	[4]	324	[4]
880591EN8
Debt Instrument
Maturity	Aug. 15, 2022
Coupon rate	1.875%
Long-term debt
Long-term Debt, net	1,000		1,000
880591ER9
Debt Instrument
Maturity	Sep. 15, 2024
Coupon rate	2.875%
Long-term debt
Long-term Debt, net	1,000		0
880591CJ9
Debt Instrument
Maturity	Nov. 01, 2025
Coupon rate	6.75%
Long-term debt
Long-term Debt, net	1,350		1,350
880591300
Debt Instrument
Maturity	Jun. 01, 2028
Coupon rate	3.83%
Long-term debt
Long-term Debt, net	324	[5]	324	[5]
880591409
Debt Instrument
Maturity	May 01, 2029
Coupon rate	3.955%
Long-term debt
Long-term Debt, net	270	[5]	270	[5]
880591DM1
Debt Instrument
Maturity	May 01, 2030
Coupon rate	7.125%
Long-term debt
Long-term Debt, net	1,000		1,000
880591DP4
Debt Instrument
Maturity	Jun. 07, 2032
Coupon rate	6.587%
Long-term debt
Long-term Debt, net	406	[4]	405	[4]
880591DV1
Debt Instrument
Maturity	Jul. 15, 2033
Coupon rate	4.70%
Long-term debt
Long-term Debt, net	472		472
880591EF5
Debt Instrument
Maturity	Jun. 15, 2034
Coupon rate	3.77%
Long-term debt
Long-term Debt, net	388	[3]	414	[3]
880591DX7
Debt Instrument
Maturity	Jun. 15, 2035
Coupon rate	4.65%
Long-term debt
Long-term Debt, net	436		436
880591CK6
Debt Instrument
Maturity	Apr. 01, 2036
Coupon rate	5.98%
Long-term debt
Long-term Debt, net	121		121
880591CS9
Debt Instrument
Maturity	Apr. 01, 2036
Coupon rate	5.88%
Long-term debt
Long-term Debt, net	1,500		1,500
880591CP5
Debt Instrument
Maturity	Jan. 15, 2038
Coupon rate	6.15%
Long-term debt
Long-term Debt, net	1,000		1,000
880591ED0
Debt Instrument
Maturity	Jun. 15, 2038
Coupon rate	5.50%
Long-term debt
Long-term Debt, net	500		500
880591EH1
Debt Instrument
Maturity	Sep. 15, 2039
Coupon rate	5.25%
Long-term debt
Long-term Debt, net	2,000		2,000
880591EP3
Debt Instrument
Maturity	Dec. 15, 2042
Coupon rate	3.50%
Long-term debt
Long-term Debt, net	1,000		1,000
880591DU3
Debt Instrument
Maturity	Jun. 07, 2043
Coupon rate	4.962%
Long-term debt
Long-term Debt, net	243	[4]	243	[4]
880591CF7
Debt Instrument
Maturity	Jul. 15, 2045
Coupon rate	6.235%
Long-term debt
Long-term Debt, net	140		140
Call date - earliest	Jul. 15, 2020
880591EB4
Debt Instrument
Maturity	Jan. 15, 2048
Coupon rate	4.875%
Long-term debt
Long-term Debt, net	500		500
880591DZ2
Debt Instrument
Maturity	Apr. 01, 2056
Coupon rate	5.375%
Long-term debt
Long-term Debt, net	1,000		1,000
880591EJ7
Debt Instrument
Maturity	Sep. 15, 2060
Coupon rate	4.625%
Long-term debt
Long-term Debt, net	1,000		1,000
880591EE8
Debt Instrument
Maturity	Nov. 15, 2014
Coupon rate	2.25%
Long-term debt
Current maturities of power bonds	3		3
880591EF5
Debt Instrument
Maturity	Dec. 15, 2014
Coupon rate	3.77%
Long-term debt
Current maturities of power bonds	26		26
880591CW0
Debt Instrument
Maturity	Jun. 15, 2015
Coupon rate	4.375%
Long-term debt
Current maturities of power bonds			0
880591DY5
Long-term debt
Current maturities of power bonds	1,000
88059TEL1
Debt Instrument
Maturity	Nov. 15, 2014
Coupon rate	2.65%
Long-term debt
Current maturities of power bonds	$ 3		$ 3

[1] Includes net exchange losses from currency transactions of $44 million at September 30, 2014 and $43 million at September 30, 2013.

[2] Includes one electronotes® issue with partial maturities of principal for each required annual payment.

[3] These Bonds include partial maturities of principal for each required annual payment.

[4] The coupon rate represents TVA’s effective interest rate.

[5] TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions. See Put and Call Options.

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Benefit Plans Components of Benefit Plans (Details) (USD $)	12 Months Ended
	Sep. 30, 2014 Number_of_defined_benefit_plan_structures Years plans	Dec. 31, 2013 Number_of_defined_benefit_plan_investment_funds	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011	Dec. 31, 2010	Sep. 30, 2014 Original benefit structure	Sep. 30, 2014 Cash Balance Benefit Structure	Sep. 30, 2014 Defined Contribution Only	Sep. 30, 2014 Maximum Original benefit structure	Sep. 30, 2014 Maximum Cash Balance Benefit Structure	Sep. 30, 2014 Maximum Defined Contribution Only	Dec. 31, 2014 Scenario, Forecast [Member]
Defined Benefit Plan Disclosure
Number of defined benefit plans	1
Number of defined contribution plans	1
Number of unfunded post-retirement health care plans	2
Number of benefit plan structures	2
Number of consecutive highest base pay years	3
Percentage of straight-time earnings for cash balance benefit credit	6.00%
Percentage added to consumer price index for interest credit of cash balance benefit	3.00%
Minimum interest credit percentage for cash balance benefit	6.00%
Maximum interest credit percentage for cash balance benefit	10.00%
Rate of cash balance benefit credit for calendar year		6.00%												6.00%
Number of defined benefit plan investment funds		2
Fixed and variable fund annual maximum contribution	$ 10,000
Fixed fund balance interest credits after January 1, 2010	6.00%
Fixed fund balance credit percentage subtracted from the actuarial rate of return after January 1, 2010	0.50%
Fixed fund interest credit rate	6.00%		6.00%
Fixed fund interest credit amount	33,000,000		36,000,000
Defined contribution plan employer matching contribution rate								0.25	0.75	0.75
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay											1.50%	4.50%	4.50%
Defined Contribution Plan, Automatic Employer Contribution										4.50%
Defined contribution plan contribution amount	$ 35,000,000		$ 34,000,000		$ 34,000,000
Market-related value phase-in period number of years	3
Number of years during which cost of living adjustment changed							4 years
Cost of Living Adjustment Cap		2.30%		0.00%		1.15%	0.00%							1.53%
Cost of living adjustment cap for calendar year 2014 and forward														5.00%
Retirement age of eligibility for cost of living adjustment after January 1, 2010							60

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Accounts Receivable, Net Accounts Receivable, Net (Tables)

12 Months Ended

Sep. 30, 2014

Accounts Receivable, Net [Abstract]

Accounts Receivable, Net

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

Accounts Receivable, Net At September 30
	2014			2013
Power receivables	$	1,576		$	1,495
Other receivables	101			73
Allowance for uncollectible accounts	(1		)	(1		)
Accounts receivable, net	$	1,676		$	1,567

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Related Parties Related Parties (Tables)

12 Months Ended

Sep. 30, 2014

Related Party Transactions [Abstract]

Related Party Transactions

Transactions with agencies of the federal government were as follows:

Related Party Transactions For the years ended, or at, September 30
	2014		2013		2012
Revenue from sales of electricity	$	128	$	120	$	117
Other income	137		102		164
Operating and maintenance	286		314		375
Cash and cash equivalents	35		38		32
Accounts receivable, net	85		58		49
Accounts payable and accrued liabilities	146		133		204
Long-term power bonds, net	3		—		—
Return on Power Program Appropriation Investment	4		7		7
Return of Power Program Appropriation Investment	10		20		20

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Kingston Fossil Plant Ash Spill Kingston Fossil Plant Ash Spill (Details) (USD $)	12 Months Ended	30 Months Ended
	Sep. 30, 2014	Sep. 30, 2014	Dec. 31, 2008 Dredge_cells Cubic_yards
Kingston Fossil Plant Ash Spill
Number of dredge cells that failed			1
Cubic yards of water and coal fly ash that flowed out of the cell			5,000,000
Total recorded estimate of Kingston cleanup costs	$ 1,100,000,000	$ 1,100,000,000
Period collected in rates	15 years
Kingston cleanup amounts spent to date	1,100,000,000	1,100,000,000
Remaining estimated Kingston liability	21,000,000	21,000,000
Kingston insurance recoveries	$ 175,000,000	$ 267,000,000

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Benefit Plans Contributions (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2014 Supplemental Employee Retirement Plans, Defined Benefit	Sep. 30, 2014 Other Post-retirement Benefits		Sep. 30, 2013 Other Post-retirement Benefits		Sep. 30, 2014 Pension Benefits		Sep. 30, 2013 Pension Benefits		Sep. 30, 2014 Other Pension Plans, Defined Benefit	Sep. 30, 2011 Other Pension Plans, Defined Benefit	Sep. 30, 2009 Other Pension Plans, Defined Benefit	Sep. 30, 2014 Minimum Other Pension Plans, Defined Benefit	Sep. 30, 2015 Scenario, Forecast [Member]	Sep. 30, 2015 Scenario, Forecast [Member] Supplemental Employee Retirement Plans, Defined Benefit	Sep. 30, 2015 Scenario, Forecast [Member] Other Pension Plans, Defined Benefit	Sep. 30, 2015 Scenario, Forecast [Member] Minimum Other Pension Plans, Defined Benefit
Defined Benefit Plan Disclosure
Employer contributions		$ 6	$ 33	[1]	$ 47	[1]	$ 256	[1]	$ 6	[1]	$ 250	$ 270	$ 1,000	$ 198		$ 5	$ 275	$ 215
Other postretirement benefit contributions	$ 47														$ 39

[1] Other Post-Retirement Benefits Employer contributions are reduced by federal reinsurance payments and provider discounts and rebates.

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Inventories, Net Inventories, Net (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Inventories, Net
Materials and supplies inventory	$ 616	$ 620
Fuel inventory	473	494
Emission allowance inventory	13	14
Allowance for inventory obsolescence	(46)	(37)
Inventories, net	$ 1,056	$ 1,091

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Fair Value Measurements Fair Value Measurements - (Tables)

12 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Valuation Techniques

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

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

Unrealized Investment Gains (Losses)

TVA recorded unrealized gains and losses related to its trading securities held as of the end of each period as follows:

	Unrealized Investment Gains (Losses) At September 30
	Financial Statement Presentation	2014		2013
SERP	Other income (expense)	$	1	$	2
LTDCP	Other income (expense)	—		—
NDT	Regulatory asset	35		48
ART	Regulatory asset	15		33

Fair Value Measurements

Fair Value Measurements At September 30, 2014
Assets	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Investments
Equity securities	$	162	$	—	$	—	$	162
Debt securities
U.S. government corporations and agencies	46		39		—		85
Corporate debt securities	—		290		—		290
Residential mortgage-backed securities	—		14		—		14
Commercial mortgage-backed securities	—		7		—		7
Collateralized debt obligations	—		29		—		29
Private partnerships	—		—		214		214
Commingled funds(2)							—
Equity security commingled funds	40		903		—		943
Debt security commingled funds	61		176		—		237
Total investments	309		1,458		214		1,981
Currency swaps(1)	—		—		—		—
Commodity contract derivatives	—		—		1		1
Commodity derivatives under FTP(1)
Swap contracts	—		—		—		—
Total commodity derivatives under FTP	—		—		—		—
Total	$	309	$	1,458	$	215	$	1,982
Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Currency swaps(1)	$	—	$	15	$	—	$	15
Interest rate swaps	—		1,348		—		1,348
Commodity contract derivatives	—		—		97		97
Commodity derivatives under FTP(1)
Swap contracts	—		34		—		34
Total commodity derivatives under FTP	—		34		—		34
Total	$	—	$	1,397	$	97	$	1,494

Notes

(1)  Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the counterparty or FCM. Deposits are made to TVA's margin cash accounts held with each FCM to offset any net liability positions in full for derivatives that are transacted with FCMs. TVA records currency swaps net of cash collateral received from or paid to the counterparty. See Note 15 — Offsetting of Derivative Assets and Liabilities.

(2) Commingled funds represent investment funds comprising multiple individual financial instruments and are classified in the table based on their existing investment portfolio as of the measurement date.  Commingled funds primarily composed of one class of security are classified in that category.

Fair Value Measurements At September 30, 2013
Assets	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Investments
Equity securities	$	151	$	—	$	—	$	151
Debt securities
U.S. government corporations and agencies	38		67		—		105
Corporate debt securities	—		255		—		255
Residential mortgage-backed securities	—		25		—		25
Commercial mortgage-backed securities	—		7		—		7
Collateralized debt obligations	—		10		—		10
Private partnerships	—		—		159		159
Commingled funds(2)							—
Equity security commingled funds	—		741		—		741
Debt security commingled funds	—		248		—		248
Total investments	189		1,353		159		1,701
Currency swaps(1)	—		28		—		28
Commodity contract derivatives	—		—		3		3
Commodity derivatives under FTP(1)
Swap contracts	—		3		—		3
Total commodity derivatives under FTP	—		3		—		3
Total	$	189	$	1,384	$	162	$	1,735
Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Currency swaps(1)	$	—	$	15	$	—	$	15
Interest rate swaps	—		1,199		—		1,199
Commodity contract derivatives	—		1		143		144
Commodity derivatives under FTP(1)
Swap contracts	—		69		—		69
Total commodity derivatives under FTP	—		69		—		69
Total	$	—	$	1,284	$	143	$	1,427

Notes

(1)  Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the counterparty or FCM. Deposits are made to TVA's margin cash accounts held with each FCM to offset any net liability positions in full for derivatives that are transacted with FCMs. TVA records currency swaps net of cash collateral received from or paid to the counterparty. See Note 15 — Offsetting of Derivative Assets and Liabilities.

(2) Commingled funds represent investment funds comprising multiple individual financial instruments and are classified in the table based on their existing investment portfolio as of the measurement date.  Commingled funds primarily composed of one class of security are classified in that category.

Fair Value Measurements Using Significant Unobservable Inputs

The following table presents a reconciliation of all assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3):

Fair Value Measurements Using Significant Unobservable Inputs
	Private Partnerships			Commodity Contract Derivatives
Balance at October 1, 2012	$	53		$	(267	)
Purchases	101			—
Issuances	—			—
Sales	(4		)	—
Settlements	—			—
Net unrealized gains (losses) deferred as regulatory assets and liabilities	9			127
Balance at September 30, 2013	159			(140		)
Purchases	39			—
Issuances	—			—
Sales	(9		)	—
Settlements	—			33
Net unrealized gains (losses) deferred as regulatory assets and liabilities	25			11
Balance at September 30, 2014	$	214		$	(96	)

Quantitative Information about Level 3 Fair Value Measurements

The following table presents quantitative information related to the significant unobservable inputs used in the measurement of fair value of TVA's assets and liabilities classified as Level 3 in the fair value hierarchy:

Quantitative Information about Level 3 Fair Value Measurements
	Fair Value at September 30 2014		Valuation Technique(s)	Unobservable Inputs	Range
Assets
Commodity contract derivatives	$	1	Discounted cash flow	Credit risk	2 - 5 %	(1)
			Pricing model	Coal supply and demand	1.0 - 1.1 billion tons/year
				Long-term market prices	$11.24 - $67.07/ton
Liabilities
Commodity contract derivatives	$	97	Pricing model	Coal supply and demand	1.0 - 1.1 billion tons/year
				Long-term market prices	$11.24 - $67.07/ton

Note

(1) Applies to two contracts.

Quantitative Information about Level 3 Fair Value Measurements
	Fair Value at September 30 2013		Valuation Technique(s)	Unobservable Inputs	Range
Assets
Commodity contract derivatives	$	3	Discounted cash flow	Credit risk	21	%	(1)
			Pricing model	Coal supply and demand	0.9 - 1.0 billion tons/year
				Long-term market prices	$10.25 - $85.25/ton
Liabilities
Commodity contract derivatives	$	143	Pricing model	Coal supply and demand	0.9 - 1.0 billion tons/year
				Long-term market prices	$10.25 - $85.25/ton

Note

(1) Applies to only one contract.

Estimated Values of Financial Instruments Not Recorded at Fair Value

The estimated values of TVA's financial instruments not recorded at fair value at September 30, 2014, and September 30, 2013, were as follows:

Estimated Values of Financial Instruments Not Recorded at Fair Value At September 30
		2014				2013
	Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value
EnergyRight® receivables (including current portion)	Level 2	$	156	$	166	$	150	$	150
Loans and other long-term receivables, net (including current portion)	Level 2	$	92	$	81	$	73	$	67
EnergyRight® purchase obligation (including current portion)	Level 2	$	190	$	215	$	186	$	222
Unfunded loan commitments	Level 2	$	—	$	18	$	—	$	13
Membership interests of variable interest entity subject to mandatory redemption (including current portion)	Level 2	$	39	$	50	$	40	$	50
Long-term outstanding power bonds (including current maturities), net	Level 2	$	22,980	$	26,889	$	22,347	$	24,603
Long-term debt of variable interest entities (including current maturities)	Level 2	$	1,311	$	1,425	$	1,341	$	1,386

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Restructuring

12 Months Ended

Sep. 30, 2014

Restructuring and Related Activities [Abstract]

Restructuring and Related Activities Disclosure [Text Block]

3.  Restructuring

TVA is undertaking cost reduction initiatives with the goal of keeping rates low, keeping reliability high, and continuing to fulfill its broader mission of environmental stewardship and economic development. TVA’s current focus is on reducing operating and maintenance costs through further efficiency gains and streamlining the organization. The goal is to reduce TVA’s operating and maintenance costs by $500 million by 2015 as compared to its 2013 budget. As part of these cost reduction initiatives, an organizational restructuring occurred in 2014, which resulted in approximately 2,000 position reductions achieved through attrition, elimination of vacant positions, and employees leaving TVA either voluntarily or involuntarily. Certain employees were eligible for severance payments as a result of these cost reduction initiatives. Remaining amounts to be paid are included in Accounts payable and accrued liabilities on the Consolidated Balance Sheets and the 2014 restructuring expense is included in Operating and maintenance on the Consolidated Statements of Operations. The table below summarizes the activity related to severance costs:

Severance Cost Liability For the year ended September 30
	2014
Severance cost liability at beginning of period	$	—
Liabilities incurred during the period	65
Actual costs paid during the period	(20		)
Severance cost liability at end of period	$	45

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Commitments and Contingencies Commitments and Contingencies - Leases (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Leases
Lease terms low end of range	1
Lease terms high end of range	80
Cost of financing	$ 124
Rental expense for operating leases	$ 75	$ 71	$ 67

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Net Completed Plant Net Completed Plant (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Completed Plant
Completed plant cost	$ 47,564	$ 47,073
Accumulated depreciation	24,589	23,157
Net completed plant	22,975	23,916
Coal-Fired
Completed Plant
Completed plant cost	14,078	13,847
Accumulated depreciation	9,065	8,429
Net completed plant	5,013	5,418
Gas and Oil-Fired
Completed Plant
Completed plant cost	3,411	3,386
Accumulated depreciation	1,094	1,008
Net completed plant	2,317	2,378
Nuclear
Completed Plant
Completed plant cost	18,489	18,725
Accumulated depreciation	9,593	9,103
Net completed plant	8,896	9,622
Transmission
Completed Plant
Completed plant cost	6,519	6,300
Accumulated depreciation	2,683	2,562
Net completed plant	3,836	3,738
Hydroelectric
Completed Plant
Completed plant cost	2,547	2,392
Accumulated depreciation	889	892
Net completed plant	1,658	1,500
Other Electrical Plant
Completed Plant
Completed plant cost	1,550	1,452
Accumulated depreciation	885	792
Net completed plant	665	660
Electric Subtotal
Completed Plant
Completed plant cost	46,594	46,102
Accumulated depreciation	24,209	22,786
Net completed plant	22,385	23,316
Multipurpose Dams
Completed Plant
Completed plant cost	928	928
Accumulated depreciation	364	356
Net completed plant	564	572
Other Stewardship
Completed Plant
Completed plant cost	42	43
Accumulated depreciation	16	15
Net completed plant	26	28
Other Subtotal
Completed Plant
Completed plant cost	970	971
Accumulated depreciation	380	371
Net completed plant	$ 590	$ 600

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Other Long-Term Liabilities Other Long-Term Liabilities (Tables)

12 Months Ended

Sep. 30, 2014

Other Liabilities, Noncurrent [Abstract]

Other Long-Term Liabilities

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

Other Long-Term Liabilities At September 30
	2014		2013
Interest rate swap liabilities	$	1,348	$	1,199
Environmental Agreements liability	108		190
EnergyRight® financing obligation	152		149
Membership interests of VIE subject to mandatory redemption	37		38
Commodity contract derivative liabilities	17		35
Commodity swap derivative liabilities	14		36
Currency swap liabilities	15		15
Other	271		199
Total other long-term liabilities	$	1,962	$	1,861

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Unaudited Quarterly Financial Information

12 Months Ended

Sep. 30, 2014

Quarterly Financial Information Disclosure [Abstract]

Unaudited Quarterly Financial Information

Unaudited Quarterly Financial Information

A summary of the unaudited quarterly results of operations for the years 2014 and 2013 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 2014
	First			Second		Third			Fourth		Total
Operating revenues	$	2,382		$	2,938	$	2,651		$	3,166	$	11,137
Operating expenses	2,164			2,362		2,453			2,569		9,548
Operating income	218			576		198			597		1,589
Net income (loss)	(67		)	295		(81		)	322		469

Unaudited Quarterly Financial Information 2013
	First			Second		Third			Fourth		Total
Operating revenues	$	2,579		$	2,741	$	2,602		$	3,034	$	10,956
Operating expenses	2,523			2,380		2,324			2,276		9,503
Operating income	56			361		278			758		1,453
Net income (loss)	(245		)	54		(12		)	474		271

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Related Parties

12 Months Ended

Sep. 30, 2014

Related Party Transactions [Abstract]

Related Parties

Related Parties

TVA is a wholly-owned corporate agency of the federal government, and because of this relationship, TVA’s revenues and expenses are included as part of the federal budget as a revolving fund.  TVA’s purpose and responsibilities as an agency are described under the “Other Agencies” section of the federal budget.

TVA currently receives no appropriations from Congress and funds its business using power system revenues, power financings, and other revenues.  TVA is a source of cash to the federal government.  With its payment of $10 million during 2014, TVA fulfilled its requirement to repay $1.0 billion of its Power Program Appropriation Investment. TVA will continue to pay a return on the outstanding balance of this investment indefinitely.  See Note 17 — 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 was renewed and has a maturity date of September 30, 2015.  Access to this credit facility or other similar financing arrangements has been available to TVA since the 1960s.  See Note 13 — Credit Facility Agreements.

In the normal course of business, TVA contracts with other federal agencies for sales of electricity and other services.  Transactions with agencies of the federal government were as follows:

Related Party Transactions For the years ended, or at, September 30
	2014		2013		2012
Revenue from sales of electricity	$	128	$	120	$	117
Other income	137		102		164
Operating and maintenance	286		314		375
Cash and cash equivalents	35		38		32
Accounts receivable, net	85		58		49
Accounts payable and accrued liabilities	146		133		204
Long-term power bonds, net	3		—		—
Return on Power Program Appropriation Investment	4		7		7
Return of Power Program Appropriation Investment	10		20		20

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Benefit Plans Postretirement Benefit Costs Deferred as Regulatory Assets (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Defined Benefit Plan Disclosure
Regulatory assets	$ 8,994	$ 9,131
Pension Benefits
Defined Benefit Plan Disclosure
Unrecognized prior service cost (credit)	(180)	(203)
Unrecognized net loss	4,337	4,113
Regulatory assets	4,157	3,910
Other Post-retirement Benefits
Defined Benefit Plan Disclosure
Unrecognized prior service cost (credit)	(39)	(45)
Unrecognized net loss	179	211
Regulatory assets	$ 140	$ 166

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Allowance for Uncollectible Accounts (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Allowance for Uncollectible Accounts
Period of time for customers to fulfill payment arrangements	90 days
Loans receivable	$ 92	$ 73
Allowance for uncollectible accounts - receivables	1	1	7	1
Additions charged to expense - receivables	1	0	6
Deductions - receivables	(1)	(6)	0
Allowance for uncollectible accounts - loans	9	10	12	11
Additions charged to expense - loans	0	0	1
Deductions - loans	(1)	(2)	0
Total allowances deducted from assets	10	11	19	12
Total additions	1	0	7
Total deductions	$ (2)	$ (8)	$ 0

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Asset Retirement Obligations Asset Retirement Obligations (Tables)

12 Months Ended

Sep. 30, 2014

Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]

Asset Retirement Obligations

Asset Retirement Obligation Activity
	Nuclear			Non-Nuclear			Total
Balance at September 30, 2012	$	2,208		$	1,081		$	3,289
Settlements (ash storage areas)	—			(37		)	(37		)
Change in estimate (ash storage areas)	66			—			66
Accretion (recorded to regulatory asset)	125			45			170
Balance at September 30, 2013	$	2,399		$	1,089		$	3,488
Settlements (ash storage areas)	—			(14		)	(14		)
Change in estimate as a result of nuclear site-specific studies	(472		)	—			(472		)
Change in estimate (ash storage areas)	—			(10		)	(10		)
Accretion (recorded to regulatory asset)	125			52			177
Balance at September 30, 2014	$	2,052		$	1,117		$	3,169		(1)

Note

(1) The current portion of ARO in the amount of $80 million is included in Accounts payable and accrued liabilities.

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Policies)

12 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

General

General

The Tennessee Valley Authority ("TVA") is a corporate agency and instrumentality of the United States that was created in 1933 by legislation enacted by the United States ("U.S.") Congress 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 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 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 over nine 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 ("Bonds").  Although TVA does not currently receive congressional appropriations, it is required to make annual payments to the U.S. Treasury as a return on the government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment").  In the 1998 Energy and Water Development Appropriations Act, Congress directed TVA to fund essential stewardship activities related to its management of the Tennessee River system and nonpower or stewardship properties with power revenues in the event that there were insufficient appropriations or other available funds to pay for such activities in any fiscal year.  Congress has not provided any appropriations to TVA to fund such activities since 1999.  Consequently, during 2000, TVA began paying for essential stewardship activities primarily with power revenues, with the remainder funded with user fees and other forms of revenues derived in connection with those activities.  The activities related to stewardship properties do not meet the criteria of an operating segment under accounting principles generally accepted in the United States of America ("GAAP").  Accordingly, these assets and properties are included as part of the power program, TVA's only operating segment.

Power rates are established by the TVA Board of Directors ("TVA Board") as authorized by the Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (as amended, 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 power system assets, retirement of outstanding Bonds in advance of maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected with TVA's power business.  In setting TVA's rates, the TVA Board is charged by the TVA Act to have due regard for the primary objectives of the TVA Act, including the objective that power shall be sold at rates as low as are feasible.  Rates set by the TVA Board are not subject to review or approval by any state or other federal regulatory body.

Fiscal Year

Fiscal Year

TVA's fiscal year ends September 30.  Years (2014, 2013, etc.) refer to TVA's fiscal years unless they are preceded by “CY,” in which case the references are to calendar years.

Cost-Based Regulation

Cost-Based Regulation

Since the TVA Board is authorized by the TVA Act to set rates for power sold to its customers, TVA is self-regulated.  Additionally, TVA's regulated rates are designed to recover its costs.  In view of demand for electricity and the level of competition, TVA believes that rates, set at levels that will recover TVA's costs, can be charged and collected.  As a result of these factors, TVA records certain assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for non-regulated entities.  Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates.  Regulatory liabilities generally represent obligations to make refunds to customers for previous collections for costs that are not likely to be incurred or deferral of gains that will be credited to customers in future periods.  TVA assesses whether the regulatory assets are probable of future recovery by considering factors such as applicable regulatory changes, potential legislation, and changes in technology.  Based on these assessments, TVA believes the existing regulatory assets are probable of recovery.  This determination reflects the current regulatory and political environment and is subject to change in the future.  If future recovery of regulatory assets ceases to be probable, or any of the other factors described above cease to be applicable, TVA would no longer be considered to be a regulated entity and would be required to write off these costs.  All regulatory asset write offs would be required to be recognized in earnings in the period in which future recovery ceases to be probable.

Basis of Presentation

Basis of Presentation

The accompanying consolidated financial statements, which have been prepared in accordance with GAAP, include the accounts of TVA and variable interest entities of which TVA is determined to be the primary beneficiary. See Note 9. Intercompany balances and transactions have been eliminated in consolidation.

Use of Estimates

Use of Estimates

The preparation of financial statements requires TVA to estimate the effects of various matters that are inherently uncertain as of the date of the consolidated financial statements.  Although the consolidated financial statements are prepared in conformity with GAAP, TVA is required to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the amounts of revenues and expenses reported during the reporting period.  Each of these estimates varies in regard to the level of judgment involved and its potential impact on TVA's financial results.  Estimates are considered critical either when a different estimate could have reasonably been used, or where changes in the estimate are reasonably likely to occur from period to period, and such use or change would materially impact TVA's financial condition, results of operations, or cash flows.

Reclassifications

Reclassifications

Cash and Cash Equivalents and Restricted Cash and Investments

Cash and Cash Equivalents

Cash includes cash on hand and non-interest bearing cash and deposit accounts. All highly liquid investments with original maturities of three months or less are considered cash equivalents.

Restricted Cash and Investments

Restricted cash and investments reflect amounts related to collateral posted with TVA by a swap counterparty.

Allowance for Uncollectible Accounts

Allowance for Uncollectible Accounts

The allowance for uncollectible accounts reflects TVA's estimate of probable losses inherent in its accounts and loans receivable balances.  TVA determines the allowance based on known accounts, historical experience, and other currently available information including events such as customer bankruptcy and/or a customer 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 $1 million at September 30, 2014, and 2013, for accounts receivable.  Additionally, loans receivable of $92 million and $73 million at September 30, 2014, and 2013, respectively, were included in Accounts receivable, net and Other long-term assets and reported net of allowances for uncollectible accounts of $9 million and $10 million at September 30, 2014, and 2013, respectively.

Revenues

Energy Prepayment Obligations and Discounts on Sales

During 2002, TVA introduced an energy prepayment program, the discounted energy units ("DEU") program.  Under this program, TVA LPCs could purchase DEUs generally in $1 million increments, and each DEU entitles the purchaser to a $.025/kilowatt-hour discount on a specified quantity of firm power over a period of years (5, 10, 15, or 20) for each kilowatt-hour in the prepaid block.  The remainder of the price of the kilowatt-hours delivered to the LPC is due upon billing.  TVA’s DEU program allowed LPCs to use cash on hand to prepay TVA for some of their power needs, providing funding to TVA and a savings to LPCs in the form of a discount on future purchases.  The LPC receives a discount on a specified volume of firm energy purchased.  The supplement to the power contract specifies the discount rate (2.5 cents per kilowatt-hour), the monthly block of kilowatt-hours to which the discount applies, the number of years (term), and contingencies upon contract termination.

TVA has not offered the DEU program since the end of 2004.  Total sales for the program since inception have been approximately $55 million.  TVA accounted for the prepayment proceeds as unearned revenue and reported the obligations to deliver power as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2013 Consolidated Balance Sheet. There were no outstanding DEU liabilities at September 30, 2014.

TVA recognizes revenue as electricity is delivered to LPCs, based on the ratio of units of kilowatt-hours delivered to total units of kilowatt-hours under contract.  At September 30, 2014, all of TVA’s obligations under the DEU program had expired, and the entire approximately $55 million had been applied against power billings on a cumulative basis during the life of the program, of which less than $1 million was recognized as noncash revenue during 2014.  Approximately $2 million and $5 million were applied against power billings during 2013 and 2012, respectively.

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 is reporting the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2014 and 2013 Consolidated Balance Sheets.  TVA expects to recognize approximately $100 million of noncash revenue in each year of the arrangement as electricity is delivered to MLGW based on the ratio of units of kilowatt-hours delivered to total units of kilowatt-hours under contract.  At September 30, 2014, approximately $1.1 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 during each of 2014, 2013, and 2012.

Discounts, which are recorded as a reduction to electricity sales, for both programs amounted to $46 million for the year ended September 30, 2014, and $47 million for each of the years ended September 30, 2013, and 2012.

Revenues

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 six 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.) 

From time to time TVA transfers fiber optic capacity on TVA’s network to telecommunications service carriers and local power company customers of TVA ("LPCs").  These transactions are structured as indefeasible rights of use ("IRUs"), which are the exclusive right to use a specified amount of fiber optic capacity for a specified term.  TVA accounts for the consideration received on transfers of fiber optic capacity for cash and on all of the other elements deliverable under an IRU as revenue ratably over the term of the agreement.  TVA does not recognize revenue on any contemporaneous exchanges of its fiber optic capacity for an IRU of fiber optic capacity of the counterparty to the exchange.

TVA engages in a wide array of arrangements in addition to power sales.  TVA records revenue when it is realized or realizable and earned when all of the following criteria are met: persuasive evidence of an arrangement exists; delivery has occurred or services have been rendered; the price or fee is fixed or determinable; and collectability is reasonably assured. Revenues from activities related to TVA’s overall mission are recorded as other operating revenue versus those that are not related to the overall mission, which are recorded in Other income (expense), net.

Inventories

Inventories

CertainFuel, Materials, and Supplies.  Coal, oil, limestone, tire-based fuel inventories, and 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. Natural gas inventories are valued using an average cost method, and a new average cost is computed monthly.

Allowance for Inventory Obsolescence.  TVA reviews material 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.  Based on the estimated value of the inventory, TVA adjusts its allowance for inventory obsolescence.

Emission Allowances.  TVA has emission allowances for sulfur dioxide ("SO₂")and nitrogen oxides ("NO_x") which are accounted for as inventory.  The average cost of allowances used each month is charged to operating expense based on tons of SO₂ and NO_x emitted during the respective compliance periods.  Allowances granted to TVA by the Environmental Protection Agency ("EPA") are recorded at zero cost.

Property, Plant, and Equipment, and Depreciation

Property, Plant, and Equipment, and Depreciation

Property, Plant, and Equipment. Additions to plant are recorded at cost, which includes direct and indirect costs and an allowance for funds used during construction ("AFUDC").  The cost of current repairs and minor replacements is charged to operating expense.  Nuclear fuel inventories, which are included in Property, plant, and equipment, are 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.

Depreciation. TVA accounts for depreciation of its properties using the composite depreciation convention of accounting.  Accordingly, the original cost of property retired is charged to accumulated depreciation. Except as described below, depreciation is generally computed on a straight-line basis over the estimated service lives of the various classes of assets. Depreciation expense for the years ended September 30, 2014, 2013, and 2012 was $1.6 billion, $1.4 billion, and $1.7 billion, respectively. Depreciation expense expressed as a percentage of the average annual depreciable completed plant was 3.42 percent for 2014, 3.12 percent for 2013, and 3.78 percent for 2012.  Average depreciation rates by asset class are as follows:

Property, Plant, and Equipment Depreciation Rates At September 30 (percent)
	2014	2013	2012
Asset Class
Nuclear	2.90	2.86	2.71
Coal-Fired	4.37	3.47	5.65
Hydroelectric	1.44	1.30	1.35
Gas and oil-fired	3.23	3.21	3.67
Transmission	2.76	2.76	2.99
Other	8.40	8.14	8.10

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 (collectively, the "Environmental Agreements”).  See Note 21 — Legal Proceedings — Environmental Agreements.  Under the Environmental Agreements, TVA committed, among other things, to retire, on a phased schedule, 18 coal-fired units. 

Consistent with the Environmental Agreements, Units 1 and 2 at John Sevier Fossil Plant ("John Sevier") were retired

on December 31, 2012, and Units 3 and 4 were idled on December 31, 2012 and subsequently retired on June 25, 2014. Units 3 and 5 at Widows Creek Fossil Plant ("Widows Creek") were retired on July 31, 2013, and Units 1, 2, 4, and 6 at Widows Creek were retired on July 31, 2014. On October 1, 2013, Colbert Fossil Plant ("Colbert") Unit 5 and Johnsonville Fossil Plant ("Johnsonville") Units 5, 6, 9, and 10 were idled. In addition, Units 7 and 8 at Johnsonville were idled March 1, 2012, and Unit 10 at Shawnee Fossil Plant ("Shawnee") was idled in October 2010 and subsequently retired on June 30, 2014.

On November 14, 2013, the TVA Board of Directors (the "TVA Board") approved the retirement of Colbert Units 1-5 no later than June 30, 2016, and the retirement of Widows Creek Unit 8. Additionally, the TVA Board approved the retirement of Paradise Fossil Plant ("Paradise") Units 1 and 2 upon the completion of a natural gas-fired plant at the Paradise location.

On August 21, 2014, the TVA Board approved the retirement of Allen Fossil Plant ("Allen") Units 1-3 upon the completion of a natural gas-fired plant at the Allen location.

Depreciation rates are adjusted to reflect current assumptions so that the units will be fully depreciated by the applicable idle dates.  As a result of TVA's decision to idle or retire units, TVA recognized $206 million and $49 million in accelerated depreciation expense related to the units during the years ended September 30, 2014, and 2013, respectively.

Capital Lease Agreements.  Property, plant, and equipment also includes assets recorded under capital lease agreements. These primarily consist of a natural gas lateral pipeline, power production facilities, water treatment assets, and land of $102 million and $42 million at September 30, 2014 and 2013, respectively, and fuel fabrication and blending facilities of $5 million at September 30, 2013. There were no obligations for fuel fabrication and blending facilities at September 30, 2014. Amortization expense related to capital leases is included in Depreciation and amortization in TVA’s statements of operations.

Allowance for Funds Used During Construction.  AFUDC capitalized during the year ended September 30, 2014, was $175 million, as compared to $168 million capitalized during the year ended September 30, 2013.  TVA capitalizes interest as AFUDC, based on the average interest rate of TVA’s outstanding debt.  The allowance is applicable to construction in progress related to projects with (1) an expected total project cost of $1.0 billion or more, and (2) an estimated construction period of at least three years in duration. During 2012 and 2011, TVA also included certain nuclear fuel inventories in the calculation of the allowance. During 2012, the TVA Board approved a change in the AFUDC methodology which removed the inclusion of nuclear fuel from the AFUDC calculation effective October 1, 2012. The accumulated balance of costs, which is used to calculate AFUDC, averaged approximately $3.3 billion for the year ended September 30, 2014. Subsequent to August 31, 2013, the accumulated balance of costs for Bellefonte Nuclear Plant ("Bellefonte") were removed from this calculation.

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 amortized primarily over five years.  At September 30, 2014 and 2013, unamortized computer software costs totaled $22 million and $5 million, respectively.  Amortization expense related to capitalized computer software costs was $31 million for each of 2014, 2013, and 2012.  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, 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 Board approval, reclassified as a regulatory asset.

Decommissioning Costs

Decommissioning Costs

TVA recognizes legal obligations associated with the future retirement of certain tangible long-lived assets.  These obligations relate to fossil fuel-fired generating plants, nuclear generating plants, hydroelectric generating plants/dams, transmission structures, and other property-related assets.  These other property-related assets include, but are not limited to, easements and coal rights.  Activities involved with retiring these assets could include decontamination and demolition of structures, removal and disposal of wastes, and site reclamation.  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.  Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset.  See Note 8 — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs andNote 12.

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. Prior to June 30, 2014, TVA based its decommissioning cost estimates on cost elements prescribed by the NRC to dismantle and decommission the radioactive portion of each site with the assumption that decommissioning would occur within the first seven years after plant shut down, which approximates the DECON method of decommissioning. The DECON method requires that radioactive contamination is 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. On June 30, 2014, TVA recorded a change in estimate based on site-specific decommissioning cost studies. Additionally, TVA determined it appropriate to reflect an increase in the probability that certain of its nuclear operating licenses will be extended and that there is a probability that it will be able to delay ultimate decommissioning activities under a SAFSTOR method of decommissioning. 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. As such, TVA ascribed probabilities to both the SAFSTOR and DECON methods of decommissioning in order to estimate its decommissioning obligation. Decommissioning cost studies will be updated for each of TVA’s nuclear units at least every five years.

Blended Low-Enriched Uranium Program

Blended Low-Enriched Uranium Program

Under the blended low-enriched uranium ("BLEU") program, TVA, the 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.  This blended nuclear fuel was first loaded in a Browns Ferry Nuclear Plant ("Browns Ferry") reactor in 2005 and is expected to continue to be used to reload the Browns Ferry reactors through at least 2016. BLEU fuel was loaded into Sequoyah Nuclear Plant ("Sequoyah") Unit 2 three times but is not expected to be used in the Sequoyah reactors in the future.

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.  The third-party fuel processors own the conversion and processing facilities and will retain title to all land, property, plant, and equipment used in the BLEU fuel program.  Over the life of the program, TVA projects that the DOE’s share of savings generated by TVA’s use of this blended nuclear fuel could result in payments to the DOE of as much as $160 million.  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.  During 2009, the DOE and TVA agreed that this obligation would be offset by amounts that the DOE expects to owe TVA in the future for certain decommissioning costs that TVA will pay on the DOE’s behalf.  Accordingly, TVA will remit the BLEU fuel savings amounts to the DOE, only after those future decommissioning costs have been offset against TVA’s obligation to the DOE. At September 30, 2014, TVA had paid out approximately $101 million for this program, and the obligation recorded was $16 million.

Investment Funds

Investment Funds

Investment funds consist primarily of trust funds designated to fund nuclear decommissioning requirements (see Note 21 — Contingencies — Decommissioning Costs), non-nuclear AROs (see Note 8 — Non-Nuclear Decommissioning Costs), the Supplemental Executive Retirement Plan ("SERP") (see Note 20 — Overview of Plans and Benefits — Supplemental Executive Retirement Plan), and the Long-Term Deferred Compensation Plan ("LTDCP"). Nuclear decommissioning funds and SERP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity market performance, while asset retirement and LTDCP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity and debt market performance. The nuclear decommissioning funds, asset retirement funds, SERP funds, and LTDCP funds are all classified as trading.

Insurance

Insurance

Although TVA uses private companies to administer its healthcare plans for eligible active and retired employees not covered by Medicare, TVA does not purchase health insurance.  Third-party actuarial specialists assist TVA in determining certain liabilities for self-insured claims.  TVA recovers the costs of claims through power rates and through adjustments to the participants’ contributions to their benefit plans.  These liabilities are included in Other liabilities on the balance sheets.

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.

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.

TVA purchases nuclear liability insurance, nuclear property, decommissioning, and decontamination insurance, and nuclear accidental outage insurance.  See Note 21— Contingencies — Nuclear Insurance.

TVA purchases excess liability insurance for aviation, auto, marine, and general liability exposures.  TVA purchases property insurance for certain conventional (non-nuclear) assets.  

The insurance policies are subject to the terms and conditions of the specific policy.  Each of the insurance policies purchased contains deductibles or self-insured retentions.  TVA recovers the costs of losses through power rates.

Research and Development Costs

Research and Development Costs

Research and development costs are expensed when incurred.  TVA’s research programs include those related to power delivery technologies, emerging technologies (clean energy, renewables, distributed resources, and energy efficiency), technologies related to generation (fossil fuel, nuclear, and hydroelectric), and environmental technologies.

Tax Equivalents

Tax Equivalents

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 and then adds back the current year fuel cost-related tax equivalent regulatory asset or liability. Fuel cost-related tax equivalent expense is recognized in the same accounting period in which the fuel cost-related revenue is recognized.

Maintenance Costs

Maintenance Costs

TVA records maintenance costs and repairs related to its property, plant, and equipment in the statements of operations as they are incurred except for the recording of certain regulatory assets for retirement and removal costs.

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Variable Interest Entities Variable Interest Entities (Policies)

12 Months Ended

Sep. 30, 2014

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Variable Interest Entity Policy

Variable Interest Entities

A VIE is an entity that either (1) has insufficient equity to permit the entity to finance its activities without additional subordinated financial support or (2) has equity investors who lack the characteristics of owning a controlling financial interest. The analysis to determine whether an entity is a VIE considers factors such as contracts with an entity, credit support for an entity, the adequacy of the equity investment of an entity, the extent of an entity's activities that either involve or are conducted on behalf of an investor with disproportionate voting rights, and the relationship of voting power to the amount of equity invested in an entity. A VIE is consolidated by its primary beneficiary. The primary beneficiary has both (i) the power to direct the activities that most significantly impact the entity's economic performance and (ii) the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. The determination of the primary beneficiary requires continual reassessment.

When TVA determines that it has a variable interest in a variable interest entity, 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.

Southaven

On August 9, 2013, TVA entered into a 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 Seven States Southaven, LLC ("SSSL"). SHLLC is a special single-purpose entity, also formed in June 2013, established to acquire and hold the membership interests of 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 scheduled amortizing, semi-annual payments due each August 15 and February 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. The sale of the SCCG notes, the membership interests in SCCG, and the SHLLC notes all closed on August 9, 2013. 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 scheduled pre-determined payments to be made to Seven States Southaven, LLC on each lease payment date by SHLLC as agreed in SHLLC’s formation documents (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.

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.

John Sevier

On January 17, 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 millionsecured 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 is allocated. 

The membership interests held by Holdco in JSCCG were purchased with proceeds from the issuance of $100 millionof secured notes (the “Holdco notes") and are subject to mandatory redemption pursuant to scheduled amortizing, semi-annual payments due each January 15 and July 15, with a final payment due on January 15, 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 on January 17, 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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Impact of New Accounting Standards and Interpretations

12 Months Ended

Sep. 30, 2014

Accounting Changes and Error Corrections [Abstract]

Impact of New Accounting Standards and Interpretations

Impact of New Accounting Standards and Interpretations

The following accounting standards became effective for TVA on October 1, 2013.

Balance Sheet. In December 2011, the Financial Accounting Standards Board ("FASB") issued guidance that requires additional disclosures relating to the rights of offset or other netting arrangements of assets and liabilities that are presented on a net or gross basis in the consolidated balance sheets. In January 2013, FASB issued additional guidance to limit the scope of the new offsetting disclosure requirements to derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and lending transactions.  The guidance requires the disclosure of the gross amounts subject to offset, actual amounts offset in accordance with GAAP, and the related net exposure. These changes became effective for TVA on October 1, 2013, and have been applied on a retrospective basis. This guidance relates solely to enhanced disclosures in the notes to the consolidated financial statements and did not have an impact on TVA's financial condition, results of operations, or cash flows.

Comprehensive Income. In February 2013, FASB issued guidance that requires public reporting companies under the Securities Act of 1933 to present information about reclassification adjustments from accumulated other comprehensive income (loss) ("AOCI") in their annual and interim financial statements in a single location. The guidance requires that companies present the effect of significant amounts reclassified from each component of AOCI based on its source and the income statement line items affected by the reclassification. This information may be disclosed either in a single note or parenthetically on the face of the financial statements. If a component is not required to be reclassified to net income in its entirety, companies must cross reference to the related footnote for additional information. These changes became effective for TVA on October 1, 2013, and have been applied on a prospective basis. TVA has chosen to disclose the required information in a single note. This guidance relates solely to enhanced disclosures and did not have an impact on TVA's financial condition, results of operations, or cash flows.

The following accounting standards have been issued, but as of September 30, 2014, were not effective and had not been adopted by TVA.

Revenue Recognition.  In May 2014, FASB issued a new revenue recognition standard that applies to revenue from contracts with customers. The standard requires that an entity recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  The standard becomes effective for TVA on October 1, 2017, and allows for either a full retrospective or a modified retrospective application.  Early adoption of the standard is not permitted. TVA is currently evaluating the potential impact of these changes on its consolidated financial statements and related disclosures and the application method to be used.

Liabilities. In February 2013, FASB issued ASU 2013-04, "Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date," which defines how entities measure obligations from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date and for which no guidance exists, except for obligations addressed within existing guidance in GAAP. The guidance also requires entities to disclose the nature and amount of the obligation as well as other information about those obligations. The standard becomes effective for TVA on October 1, 2014. Retrospective presentation for all comparative periods presented is required and early adoption is permitted. TVA has evaluated the impact of adopting this guidance and expects no material impact on TVA's financial condition, results of operations, or cash flows.

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Kingston Fossil Plant Ash Spill Kingston Fossil Plant Ash Spill (Policies)

12 Months Ended

Sep. 30, 2014

Environmental Remediation Obligations [Abstract]

Kingston Fossil Plant Ash Spill Policy

Financial Impact

TVA recorded an estimate of $1.1 billion for the cost of cleanup related to this event.  In August 2009, TVA began using regulatory accounting treatment to defer all actual costs already incurred and expected future costs related to the ash spill.  The cost is being charged to expense as it is collected in rates over 15 years, beginning October 1, 2009.  

Amounts spent since the event through September 30, 2014, totaled $1.1 billion.  The remaining estimated liability at September 30, 2014, was $21 million and is included in Current liabilities.

TVA has not included the following categories of costs in the above estimate since it has been determined that these costs are currently either not probable or not reasonably estimable: penalties (other than the penalties set out in a June 2010 TDEC order), regulatory directives, natural resources damages (other than payments required under a memorandum of agreement with TDEC and the U.S. Fish and Wildlife Service establishing a process and a method for resolving the natural resource damages claim), future lawsuits, future claims, long-term environmental impact costs, final long-term disposition of the ash processing area, and costs associated with new laws and regulations.  There are certain other costs that will be incurred that have not been included in the estimate as they are appropriately accounted for in other areas of the consolidated financial statements.  Associated capital asset purchases are recorded in property, plant, and equipment.  Ash handling and disposition costs from current plant operations are recorded in operating expenses.  A portion of the dredge cell closure costs are also excluded from the estimate, as they are included in the non-nuclear ARO liability.

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Currency Swaps Outstanding (Details) (GBP £) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014
Derivative
Number of British pound sterling denominated bond transactions	3
1999 Currency Swap Contract
Derivative
Effective Date of Currency Swap Contract	1999
Associated TVA bond issues currency exposure	£ 200
Expiration Date of Swap	2021
Overall effective cost to TVA	5.81%
2001 Currency Swap Contract
Derivative
Effective Date of Currency Swap Contract	2001
Associated TVA bond issues currency exposure	250
Expiration Date of Swap	2032
Overall effective cost to TVA	6.59%
2003 Currency Swap Contract
Derivative
Effective Date of Currency Swap Contract	2003
Associated TVA bond issues currency exposure	£ 150
Expiration Date of Swap	2043
Overall effective cost to TVA	4.96%

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Commitments and Contingencies Commitments and Contingencies - Energy Prepayment Obligations (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014
Obligations
2015	$ 100
2016	100
2017	100
2018	100
2019	10
Thereafter	0
Total	$ 410

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Other Long-Term Assets Other Long-Term Assets (Tables)

12 Months Ended

Sep. 30, 2014

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

Other Long-Term Assets

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

Other Long-Term Assets At September 30
	2014		2013
EnergyRight® receivables	$	123	$	117
Unamortized debt issue cost of power bonds	68		75
Loans and other long-term receivables, net	87		73
Coal contract derivative assets	—		1
Prepaid capacity payments	58		62
Currency swap assets, net	—		28
Restricted cash	64		—
Other	83		89
Total other long-term assets	$	483	$	445

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Unaudited Quarterly Financial Information Unaudited Quarterly Financial Information (Tables)

12 Months Ended

Sep. 30, 2014

Quarterly Financial Information Disclosure [Abstract]

Unaudited Quarterly Financial Information

Unaudited Quarterly Financial Information 2014
	First			Second		Third			Fourth		Total
Operating revenues	$	2,382		$	2,938	$	2,651		$	3,166	$	11,137
Operating expenses	2,164			2,362		2,453			2,569		9,548
Operating income	218			576		198			597		1,589
Net income (loss)	(67		)	295		(81		)	322		469

Unaudited Quarterly Financial Information 2013
	First			Second		Third			Fourth		Total
Operating revenues	$	2,579		$	2,741	$	2,602		$	3,034	$	10,956
Operating expenses	2,523			2,380		2,324			2,276		9,503
Operating income	56			361		278			758		1,453
Net income (loss)	(245		)	54		(12		)	474		271

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Debt and Other Obligations Debt and Other Obligations - Short-Term Debt (Details) (USD $) In Billions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Short-term Debt
Short-term debt, weighted average interest rate		0.04%	0.09%
Short-term debt, maximum amount outstanding during period	$ 2.4	$ 3.4	$ 3.2
Short-term debt, average amount outstanding	$ 1.7	$ 1.9	$ 1.1
Weighted average interest rates during period	0.05%	0.08%	0.08%

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CONSOLIDATED STATEMENTS OF OPERATIONS (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Operating revenues
Revenue from sales of electricity	$ 10,999	$ 10,829	$ 11,086
Other revenue	138	127	134
Total operating revenues	11,137	10,956	11,220
Operating expenses
Fuel	2,730	2,820	2,680
Purchased power	1,094	1,027	1,189
Operating and maintenance	3,341	3,428	3,510
Depreciation and amortization	1,843	1,680	1,919
Tax equivalents	540	548	622
Total operating expenses	9,548	9,503	9,920
Operating income	1,589	1,453	1,300
Other income (expense), net	49	44	33
Interest expense
Interest expense	1,344	1,394	1,444
Allowance for funds used during construction and nuclear fuel expenditures	(175)	(168)	(171)
Net interest expense	1,169	1,226	1,273
Net income (loss)	$ 469	$ 271	$ 60

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Debt and Other Obligations Debt and Other Obligations (Tables)

12 Months Ended

Sep. 30, 2014

Debt and Other Obligations [Abstract]

Debt Securities Activity

The table below summarizes the long-term debt securities activity for the period from October 1, 2012, to September 30, 2014.

Debt Securities Activity For the years ended September 30
	2014			2013
Issues
Variable interest entities	$	—		$	360
electronotes®	—			152
2012 Series B(1)	—			1,000
2013 Series A(2)	—			1,000
2014 Series A(3)	1,000			—
Discount on debt issues	(11		)	(30		)
Total	$	989		$	2,482
Redemptions/Maturities(4)
Variable interest entities	$	30		$	13
electronotes®	335			50
1998 Series C	—			1,359
1998 Series D	—			2
1999 Series A	—			1
2003 Series C	—			940
2009 Series A	4			4
2009 Series B	26			2
Total	$	395		$	2,371

Notes

(1) The 2012 Series B bonds were issued at 97.49 percent of par.

(2) The 2013 Series A bonds were issued at 99.52 percent of par.

(3) The 2014 Series A bonds were issued at 98.94 percent of par.

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

Debt Outstanding

Total debt outstanding at September 30, 2014, and 2013, consisted of the following:

Short-Term Debt At September 30
CUSIP or Other Identifier	Maturity	Call/(Put) Date	Coupon Rate	2014		2013
Short-term debt, net of discounts				$	596	$	2,432
Current maturities of long-term debt of variable interest entities issued at par				32		30
Current maturities of power bonds issued at par
880591EE8	11/15/2014		2.250%	3		3
880591EF5	12/15/2014		3.770%	26		26
880591DY5	6/15/2015		4.375%	1,000		—
88059TEL1	11/15/2014		2.650%	3		3
Total current maturities of power bonds issued at par				1,032		32
Total current debt outstanding, net				$	1,660	$	2,494

Long-Term Debt(1) At September 30
CUSIP or Other Identifier	Maturity	Coupon Rate			Call Date	2014 Par		2013 Par		Stock Exchange Listings
electronotes®(2)	05/15/2020 - 02/15/2043	2.375 - 4.375%			2/15/2015 - 02/15/2018	$	387	$	723	None
880591DY5	6/15/2015	4.375%				—		1,000		New York, Luxembourg
880591EE8(3)	11/15/2015	2.250%				2		4		None
880591DS8	12/15/2016	4.875%				524		524		New York
880591EA6	7/18/2017	5.500%				1,000		1,000		New York, Luxembourg
880591CU4	12/15/2017	6.250%				650		650		New York
880591EC2	4/1/2018	4.500%				1,000		1,000		New York, Luxembourg
880591EQ1	10/15/2018	1.750%				1,000		1,000		New York
880591EL2	2/15/2021	3.875%				1,500		1,500		New York
880591DC3	6/7/2021	5.805%	(4	)		324		324		New York, Luxembourg
880591EN8	8/15/2022	1.875%				1,000		1,000		New York
880591ER9	9/15/2024	2.875%				1,000		—		New York
880591CJ9	11/1/2025	6.750%				1,350		1,350		New York, Hong Kong, Luxembourg, Singapore
880591300(5)	6/1/2028	3.830%				324		324		New York
880591409(5)	5/1/2029	3.955%				270		270		New York
880591DM1	5/1/2030	7.125%				1,000		1,000		New York, Luxembourg

880591DP4	6/7/2032	6.587%	(4	)		406			405			New York, Luxembourg
880591DV1	7/15/2033	4.700%				472			472			New York, Luxembourg
880591EF5(3)	6/15/2034	3.770%				388			414			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%	(4	)		243			243			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
Subtotal						22,037			22,400
Unamortized discounts, premiums, and other						(89		)	(85		)
Total long-term outstanding power bonds, net						21,948			22,315
Long-term debt of variable interest entities						1,279			1,311
Total long-term debt, net						$	23,227		$	23,626

Notes

(1)  Includes net exchange losses from currency transactions of $44 million at September 30, 2014 and $43 million at September 30, 2013.

(2)  Includes one electronotes^® issue with partial maturities of principal for each required annual payment.

(3)  These Bonds include partial maturities of principal for each required annual payment.

(4)  The coupon rate represents TVA’s effective interest rate.

(5)  TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions.  See Put and Call Options.

Maturities Due

Maturities Due in the Year Ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Long-term power bonds and long-term debt of variable interest entities including current maturities(1)	$	1,064	$	65	$	1,590	$	1,718	$	1,070	$	18,829	$	24,336
Short-term debt, net of discounts	596		—		—		—		—		—		596

Note

(1) Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million.

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Supplemental Cash Flow Information Supplemental Cash Flow Information (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Supplemental Cash Flow Information
Interest paid	$ 1,300,000,000	$ 1,300,000,000	$ 1,400,000,000
Interest capitalized	175,000,000	168,000,000	171,000,000
Bellefonte amounts included in Construction expenditures		162,000,000	212,000,000
Financing non-cash activity for capital leases	70,000,000	20,000,000	6,000,000
Accounts payable and accrued liabilities
Supplemental Cash Flow Information
Construction in progress and Nuclear fuel expenditures	$ 391,000,000	$ 270,000,000	$ 204,000,000

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Commitments and Contingencies Commitments and Contingencies - Table (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013
Obligations
Time period shown for contractual commitments	5 years
2015	$ 1,064
2016	65
2017	1,590
2018	1,718
2019	1,070
Thereafter	18,829
Total	24,336
Total	18		13
2015	100
2016	100
2017	100
2018	100
2019	10
Thereafter	0
Total	410
Foreign currency exchange loss	44		43
Net discount on sale of Bonds	89
Debt
Obligations
2015	1,628
2016	32
2017	1,555
2018	1,682
2019	1,032
Thereafter	17,692
Total	23,621	[1]
Debt of VIEs
Obligations
2015	32
2016	33
2017	35
2018	36
2019	38
Thereafter	1,137
Total	1,311
Financial Instruments Subject to Mandatory Redemption, Financial Instrument [Domain]
Obligations
2015	2
2016	2
2017	2
2018	2
2019	2
Thereafter	29
Total	39
Lease Obligations - Capital
Obligations
2015	13
2016	13
2017	13
2018	13
2019	12
Thereafter	167
Total	231
Lease Obligations - Non-Cancelable Operating
Obligations
2015	38
2016	36
2017	34
2018	27
2019	25
Thereafter	63
Total	223
Purchase Obligations - Power
Obligations
2015	220
2016	222
2017	232
2018	235
2019	239
Thereafter	3,364
Total	4,512
Purchase Obligations - Fuel
Obligations
2015	1,335
2016	862
2017	477
2018	552
2019	492
Thereafter	1,579
Total	5,297
Purchase Obligations - Other
Obligations
2015	304
2016	215
2017	202
2018	199
2019	192
Thereafter	1,640
Total	2,752
Unfunded Loan Commitment [Member]
Obligations
2015	13
Total	13
Payments on Other Financings
Obligations
2015	104
2016	104
2017	104
2018	104
2019	96
Thereafter	305
Total	817
Total
Obligations
2015	3,689
2016	1,519
2017	2,654
2018	2,850
2019	2,128
Thereafter	25,976
Total	$ 38,816

[1] Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) Statement (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 469	$ 271	$ 60
Net unrealized gain (loss) on cash flow hedges	4	78	99
Reclassification to earnings from cash flow hedges	(2)	(1)	(35)
Total other comprehensive income (loss)	2	77	64
Total comprehensive income (loss)	$ 471	$ 348	$ 124

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Proprietary Capital Proprietary Capital - Accumulated Other Comprehensive Income (Loss) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Accumulated Other Comprehensive Income (Loss)
Net effect on earnings	$ 0	$ 0	$ 0
Net unrealized gain (loss) on future cash flow hedges	4	78	99
Reclassification to earnings from cash flow hedges	2	1	35
Reclassification to earnings from cash flow hedges in the next twelve months	$ 37

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Restructuring (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Restructuring and Related Activities [Abstract]
Expected increase (decrease) in operation and maintenance expense	$ (500)
Severance cost liability	45	0
Liabilities incurred during the period	65
Actual costs paid during the period	$ (20)
Approximate number of positions eliminated	2,000

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Benefit Plans Amounts Recognized on TVA's Consolidated Balance Sheets (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013
Defined Benefit Plan Disclosure
Regulatory assets	$ 8,994		$ 9,131
Accounts payable and accrued liabilities	(2,029)		(1,627)
Post-retirement and post-employment benefit obligations	(5,839)		(5,348)
Pension Benefits
Defined Benefit Plan Disclosure
Regulatory assets	4,157		3,910
Accounts payable and accrued liabilities	(5)		(5)
Post-retirement and post-employment benefit obligations	(4,753)	[1]	(4,245)	[1]
Other Post-retirement Benefits
Defined Benefit Plan Disclosure
Regulatory assets	140		166
Accounts payable and accrued liabilities	(38)		(39)
Post-retirement and post-employment benefit obligations	(614)	[1]	(617)	[1]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent [Member]
Defined Benefit Plan Disclosure
Postemployment benefits liability, noncurrent	$ 472		$ 486

[1] Table above excludes $472 million and $486 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, 2014 and 2013, respectively.

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Tables)

12 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

Allowance for Uncollectible Accounts [Table Text Block]

The following table contains information about TVA’s current estimates related to uncollectible accounts.

Allowance for Uncollectible Accounts (in millions)
Description	Balance at beginning of year		Additions charged to expense		Deductions			Balance at end of year
For the year ended September 30, 2014
Allowance for uncollectible accounts
Receivables	$	1	$	1	$	(1	)	$	1
Loans	10		—		(1		)	9
Total allowances deducted from assets	$	11	$	1	$	(2	)	$	10
For the year ended September 30, 2013
Allowance for uncollectible accounts
Receivables	$	7	$	—	$	(6	)	$	1
Loans	12		—		(2		)	10
Total allowances deducted from assets	$	19	$	—	$	(8	)	$	11
For the year ended September 30, 2012
Allowance for uncollectible accounts
Receivables	$	1	$	6	$	—		$	7
Loans	11		1		—			12
Total allowances deducted from assets	$	12	$	7	$	—		$	19

Property, Plant, and Equipment Depreciation Rates

Average depreciation rates by asset class are as follows:

Property, Plant, and Equipment Depreciation Rates At September 30 (percent)
	2014	2013	2012
Asset Class
Nuclear	2.90	2.86	2.71
Coal-Fired	4.37	3.47	5.65
Hydroelectric	1.44	1.30	1.35
Gas and oil-fired	3.23	3.21	3.67
Transmission	2.76	2.76	2.99
Other	8.40	8.14	8.10

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Regulatory Assets and Liabilities Regulatory Assets and Liabilities (Details) (USD $)	12 Months Ended	30 Months Ended			12 Months Ended		12 Months Ended				12 Months Ended
	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2013	Jul. 31, 2005 Units	Sep. 30, 2014 Deferred Nuclear Generating Units and Construction Costs	Jul. 31, 2005 Deferred Nuclear Generating Units and Construction Costs	Sep. 30, 2014 Environmental Cleanup Costs - Kingston Ash Spill	Sep. 30, 2010 Environmental Cleanup Costs - Kingston Ash Spill	Sep. 30, 2009 Environmental Cleanup Costs - Kingston Ash Spill	Sep. 30, 2014 Environmental Agreements	Sep. 30, 2014 Energy Efficiency Projects Environmental Agreements	Sep. 30, 2014 Paid to States Environmental Agreements	Sep. 30, 2014 Civil Penalties Environmental Agreements	Sep. 30, 2014 Derivatives Under FTP		Sep. 30, 2013 Derivatives Under FTP		Sep. 30, 2014 Deferred nuclear generating units
Regulatory Assets and Liabilities
Net unrealized gains (losses)														$ 103,000,000	[1]	$ 166,000,000	[1]
Investment in deferred generating units						3,900,000,000
Number of deferred generating units				2
Regulatory Noncurrent Asset, Amortization Period					P10Y
Remaining balance to be included in plant asset balance at completion					619,000,000
Regulatory Assets	9,475,000,000	9,475,000,000	9,692,000,000															1,500,000,000
Yearly amortization of Deferred nuclear generating units	237,000,000
Initial regulatory asset										360,000,000
Investment in environmental agreement projects										290,000,000
Amount to be provided to fund environmental projects										60,000,000
Amount to be paid in civil penalties										10,000,000
Regulatory asset amount expensed											138,000,000	50,000,000	10,000,000
Total recorded estimate of Kingston cleanup costs	1,100,000,000	1,100,000,000					1,100,000,000		933,000,000
Kingston insurance recoveries	175,000,000	267,000,000
Estimate increase								$ 192,000,000
Current regulatory asset amortization period							12 months

[1] Fair values of certain derivatives under the FTP that were in net liability positions totaling $69 million and $100 million at September 30, 2014 and September 30, 2013, respectively, are recorded in TVA's margin cash accounts in Other current assets. These derivatives are transacted with futures commission merchants, and cash deposits have been posted to the margin cash accounts held with each futures commission merchant to offset the net liability positions in full.

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Fair Value Measurements

12 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

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

Valuation Techniques

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

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

A financial instrument's level within the fair value hierarchy (where Level 3 is the lowest and Level 1 is the highest) 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 LTDCP assets, all changes in fair value of these assets and liabilities have been reflected in regulatory assets, regulatory liabilities, or accumulated other comprehensive income (loss) on TVA's consolidated balance sheets, and consolidated statements of comprehensive income (loss). Except for gains and losses on SERP and LTDCP assets, there has been no impact to TVA's consolidated statements of operations or its consolidated statements of cash flows related to these fair value measurements.

Investments Funds

At September 30, 2014, Investment funds were composed of $2.0 billion of securities classified as trading and measured at fair value and less than $1 million of equity investments not required to be measured at fair value. Trading securities are held in the NDT, ART, SERP, and LTDCP. The NDT holds funds for the ultimate decommissioning of TVA's nuclear power plants. The ART holds funds for the costs related to the future closure and retirement of TVA's long-lived assets. TVA established a SERP for certain executives in critical positions to provide supplemental pension benefits tied to compensation that exceeds limits set by Internal Revenue Service ("IRS") rules applicable to the qualified defined benefit pension plan. The LTDCP is designed to provide long-term incentives to executives to encourage them to stay with TVA and to provide competitive levels of total compensation to such executives. The NDT and SERP are invested in securities generally designed to achieve a return in line with overall equity market performance, and the ART and LTDCP are invested in securities generally designed to achieve a return in line with overall debt and equity market performance.

The NDT, ART, SERP, and LTDCP are composed of multiple types of investments and are managed by external institutional managers. Most U.S. and international equities, Treasury Inflation-Protected Securities, real estate investment trust securities, 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 partnership 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.  Investments in private partnerships generally involve a three-to-four-year period where the investor contributes capital.  This is followed by a period of distribution, typically over several years.  The investment period is generally, at a minimum, ten years or longer.  The NDT had unfunded commitments related to private partnerships of $113 million at September 30, 2014.  These investments have no redemption or limited redemption options and may also impose restrictions on the NDT’s ability to liquidate its investments.  There are no readily available quoted exchange prices for these investments.  The fair value of the investments is based on TVA’s ownership percentage of the fair value of the underlying investments as provided by the investment managers.  These investments are typically valued on a quarterly basis.  TVA’s private partnership 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 Level 3 within the fair value hierarchy. 

Commingled funds represent investment funds comprising multiple individual financial instruments. The commingled funds held by the NDT, ART, SERP, and LTDCP 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 (Level 1) or measured using observable inputs for similar instruments (Level 2). 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 Level 1 or Level 2 valuations.

Realized and unrealized gains and losses on trading 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 liability or asset account in accordance with TVA's regulatory accounting policy. See Note 1 — Cost-Based Regulation. TVA recorded unrealized gains and losses related to its trading securities held as of the end of each period as follows:

	Unrealized Investment Gains (Losses) At September 30
	Financial Statement Presentation	2014		2013
SERP	Other income (expense)	$	1	$	2
LTDCP	Other income (expense)	—		—
NDT	Regulatory asset	35		48
ART	Regulatory asset	15		33

Currency and Interest Rate Derivatives

See Note 15 — 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 and interest rate swaps. These swaps are classified as Level 2 valuations and are valued based on income approaches using observable market inputs for similar instruments.

Commodity Contract Derivatives and Commodity Derivatives Under FTP

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.

Commodity Derivatives Under FTP. These contracts are valued based on market approaches which utilize Chicago Mercantile Exchange ("CME") quoted prices and other observable inputs. Futures and options contracts settled on the CME are classified as Level 1 valuations. Swap contracts are valued using a pricing model based on CME inputs and are subject to nonperformance risk outside of the exit price. These contracts are classified as Level 2 valuations.

See Note 15 — Derivatives Not Receiving Hedge Accounting Treatment — Commodity Derivatives and— Derivatives Under FTP for a discussion of the nature and purpose of coal contracts and derivatives under TVA's FTP.

Nonperformance Risk

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

Nonperformance risk for most of TVA's derivative instruments is an adjustment to the initial asset/liability fair value. TVA adjusts for nonperformance risk, both for 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 company. TVA discounts each financial instrument using the historical default rate (as reported by Moody’s for CY 1983 to CY 2013) 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, 2014.

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, 2014, and September 30, 2013. 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, 2014
Assets	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Investments
Equity securities	$	162	$	—	$	—	$	162
Debt securities
U.S. government corporations and agencies	46		39		—		85
Corporate debt securities	—		290		—		290
Residential mortgage-backed securities	—		14		—		14
Commercial mortgage-backed securities	—		7		—		7
Collateralized debt obligations	—		29		—		29
Private partnerships	—		—		214		214
Commingled funds(2)							—
Equity security commingled funds	40		903		—		943
Debt security commingled funds	61		176		—		237
Total investments	309		1,458		214		1,981
Currency swaps(1)	—		—		—		—
Commodity contract derivatives	—		—		1		1
Commodity derivatives under FTP(1)
Swap contracts	—		—		—		—
Total commodity derivatives under FTP	—		—		—		—
Total	$	309	$	1,458	$	215	$	1,982
Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Currency swaps(1)	$	—	$	15	$	—	$	15
Interest rate swaps	—		1,348		—		1,348
Commodity contract derivatives	—		—		97		97
Commodity derivatives under FTP(1)
Swap contracts	—		34		—		34
Total commodity derivatives under FTP	—		34		—		34
Total	$	—	$	1,397	$	97	$	1,494

Notes

(1)  Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the counterparty or FCM. Deposits are made to TVA's margin cash accounts held with each FCM to offset any net liability positions in full for derivatives that are transacted with FCMs. TVA records currency swaps net of cash collateral received from or paid to the counterparty. See Note 15 — Offsetting of Derivative Assets and Liabilities.

(2) Commingled funds represent investment funds comprising multiple individual financial instruments and are classified in the table based on their existing investment portfolio as of the measurement date.  Commingled funds primarily composed of one class of security are classified in that category.

Fair Value Measurements At September 30, 2013
Assets	Quoted Prices in Active  Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Investments
Equity securities	$	151	$	—	$	—	$	151
Debt securities
U.S. government corporations and agencies	38		67		—		105
Corporate debt securities	—		255		—		255
Residential mortgage-backed securities	—		25		—		25
Commercial mortgage-backed securities	—		7		—		7
Collateralized debt obligations	—		10		—		10
Private partnerships	—		—		159		159
Commingled funds(2)							—
Equity security commingled funds	—		741		—		741
Debt security commingled funds	—		248		—		248
Total investments	189		1,353		159		1,701
Currency swaps(1)	—		28		—		28
Commodity contract derivatives	—		—		3		3
Commodity derivatives under FTP(1)
Swap contracts	—		3		—		3
Total commodity derivatives under FTP	—		3		—		3
Total	$	189	$	1,384	$	162	$	1,735
Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Currency swaps(1)	$	—	$	15	$	—	$	15
Interest rate swaps	—		1,199		—		1,199
Commodity contract derivatives	—		1		143		144
Commodity derivatives under FTP(1)
Swap contracts	—		69		—		69
Total commodity derivatives under FTP	—		69		—		69
Total	$	—	$	1,284	$	143	$	1,427

Notes

(1)  Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the counterparty or FCM. Deposits are made to TVA's margin cash accounts held with each FCM to offset any net liability positions in full for derivatives that are transacted with FCMs. TVA records currency swaps net of cash collateral received from or paid to the counterparty. See Note 15 — Offsetting of Derivative Assets and Liabilities.

(2) Commingled funds represent investment funds comprising multiple individual financial instruments and are classified in the table based on their existing investment portfolio as of the measurement date.  Commingled funds primarily composed of one class of security are classified in that category.

TVA uses internal and external valuation specialists for the calculation of its 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 assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3):

Fair Value Measurements Using Significant Unobservable Inputs
	Private Partnerships			Commodity Contract Derivatives
Balance at October 1, 2012	$	53		$	(267	)
Purchases	101			—
Issuances	—			—
Sales	(4		)	—
Settlements	—			—
Net unrealized gains (losses) deferred as regulatory assets and liabilities	9			127
Balance at September 30, 2013	159			(140		)
Purchases	39			—
Issuances	—			—
Sales	(9		)	—
Settlements	—			33
Net unrealized gains (losses) deferred as regulatory assets and liabilities	25			11
Balance at September 30, 2014	$	214		$	(96	)

There were $57 million of realized losses related to the instruments measured at fair value using significant unobservable inputs during the year ended September 30, 2014. All unrealized gains and losses related to these instruments have been reflected as increases or decreases in regulatory assets and liabilities. See Note 8.

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 2014		Valuation Technique(s)	Unobservable Inputs	Range
Assets
Commodity contract derivatives	$	1	Discounted cash flow	Credit risk	2 - 5 %	(1)
			Pricing model	Coal supply and demand	1.0 - 1.1 billion tons/year
				Long-term market prices	$11.24 - $67.07/ton
Liabilities
Commodity contract derivatives	$	97	Pricing model	Coal supply and demand	1.0 - 1.1 billion tons/year
				Long-term market prices	$11.24 - $67.07/ton

Note

(1) Applies to two contracts.

Quantitative Information about Level 3 Fair Value Measurements
	Fair Value at September 30 2013		Valuation Technique(s)	Unobservable Inputs	Range
Assets
Commodity contract derivatives	$	3	Discounted cash flow	Credit risk	21	%	(1)
			Pricing model	Coal supply and demand	0.9 - 1.0 billion tons/year
				Long-term market prices	$10.25 - $85.25/ton
Liabilities
Commodity contract derivatives	$	143	Pricing model	Coal supply and demand	0.9 - 1.0 billion tons/year
				Long-term market prices	$10.25 - $85.25/ton

Note

(1) Applies to only one contract.

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 market value of the financial instruments held at September 30, 2014, and September 30, 2013, 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, 2014, and September 30, 2013, were as follows:

Estimated Values of Financial Instruments Not Recorded at Fair Value At September 30
		2014				2013
	Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value
EnergyRight® receivables (including current portion)	Level 2	$	156	$	166	$	150	$	150
Loans and other long-term receivables, net (including current portion)	Level 2	$	92	$	81	$	73	$	67
EnergyRight® purchase obligation (including current portion)	Level 2	$	190	$	215	$	186	$	222
Unfunded loan commitments	Level 2	$	—	$	18	$	—	$	13
Membership interests of variable interest entity subject to mandatory redemption (including current portion)	Level 2	$	39	$	50	$	40	$	50
Long-term outstanding power bonds (including current maturities), net	Level 2	$	22,980	$	26,889	$	22,347	$	24,603
Long-term debt of variable interest entities (including current maturities)	Level 2	$	1,311	$	1,425	$	1,341	$	1,386

Due to the short-term maturity of Cash and cash equivalents, Restricted cash and investments, and Short-term debt, net (each considered a Level 1 valuation classification), the carrying amounts of these instruments 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 traded in the public market is determined by multiplying the par value of the debt by the indicative market price at the balance sheet date. The fair value of other long-term debt and membership interests of variable interest entity subject to mandatory redemption is estimated by determining the present value of future cash flows using current market rates for similar obligations, giving effect to credit ratings and remaining maturities.

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Restructuring (Tables)

12 Months Ended

Sep. 30, 2014

Restructuring and Related Activities [Abstract]

Severance Cost Liability Activity

The table below summarizes the activity related to severance costs:

Severance Cost Liability For the year ended September 30
	2014
Severance cost liability at beginning of period	$	—
Liabilities incurred during the period	65
Actual costs paid during the period	(20		)
Severance cost liability at end of period	$	45

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Benefit Plans Obligations and Funded Status (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Pension Benefits
Change in benefit obligation
Benefit obligation	$ 12,265		$ 11,471		$ 11,995
Service cost	130		154		139
Interest cost	558		468		490
Plan participants' contributions	28		29
Amendments	2		4
Actuarial loss (gain)	(722)		549
Net transfers from variable fund/401(k) plan	13		4
Expenses paid	(6)		(6)
Benefits paid	(653)		(628)
Change in plan assets
Fair value of net plan assets	7,507		7,221		7,029
Actual return on plan assets	648		787
Employer contributions	256	[1]	6	[1]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Funded status	(4,758)		(4,250)
Discount rate	4.45%		5.00%		4.00%
Amount of defined benefit plan actuarial gain (loss) from discount rate change	(729)		1,400
Amount of defined benefit plan actuarial gain (loss) from reduction in workforce	(36)
Impact of previously excluded retiree benefits			(705)
Amount of defined benefit plan actuarial gain (loss) from retirement rate assumption change	88
Other Post-retirement Benefits
Change in benefit obligation
Benefit obligation	652		656		811
Service cost	18		24		19
Interest cost	32		31		35
Collections	93	[2]	79	[2]
Amendments	0		0
Actuarial loss (gain)	21		163
Net transfers from variable fund/401(k) plan	0		0
Expenses paid	0		0
Benefits paid	(126)		(126)
Change in plan assets
Fair value of net plan assets	0		0		0
Actual return on plan assets	0		0
Employer contributions	33	[1]	47	[1]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Funded status	(652)		(656)
Discount rate	4.50%		5.05%		4.00%
Amount of defined benefit plan actuarial gain (loss) from discount rate change	(43)		93
Amount of defined benefit plan actuarial gain (loss) from reduction in workforce	(17)
Amount of defined benefit plan actuarial gain (loss) from excise tax change			(33)
Amount of defined benefit plan actuarial gain (loss) from plan demographic experience changes	64		43
Amount of defined benefit plan actuarial gain (loss) from retirement rate assumption change	$ 16

[1] Other Post-Retirement Benefits Employer contributions are reduced by federal reinsurance payments and provider discounts and rebates.

[2] Collections include retiree contributions as well as federal reinsurance payments and provider discounts and rebates.

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Other Income (Expense), Net

12 Months Ended

Sep. 30, 2014

Other Income and Expenses [Abstract]

Other Income (Expense), Net

Other Income (Expense), Net

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

Other Income (Expense), Net For the years ended September 30
	2014		2013			2012
Interest income	$	23	$	23		$	21
External services	19		18			7
Gains (losses) on investments	6		4			5
Miscellaneous	1		(1		)	—
Total other income (expense), net	$	49	$	44		$	33

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Other Long-Term Liabilities Other Long-Term Liabilities (Details) (USD $) In Millions, unless otherwise specified				12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Aug. 09, 2013	Sep. 30, 2014 Energy Right Program	Sep. 30, 2014 Other long-term liabilities	Sep. 30, 2013 Other long-term liabilities	Sep. 30, 2014 Accounts payable and accrued liabilities	Sep. 30, 2013 Accounts payable and accrued liabilities
Other Long-Term Liabilities
Number of days in default				180 days
Interest rate swap liabilities	$ 1,348	$ 1,199			$ 1,348	$ 1,199
Environmental agreements liability					108	190
EnergyRight financing obligation	215	222			152	149	38	37
Membership interests of VIE subject to mandatory redemption					37	38
Commodity contract derivative liabilities					17	35
Commodity swap derivative liabilities					14	36
Currency swap liabilities	15	15			15	15
Other					271	199
Total other long-term liabilities	1,962	1,861
Percentage of membership interests issued			100.00%
Membership interests of VIE subject to mandatory redemption	50	50	40
SCCG balloon payment			4
Membership interests of VIE subject to mandatory redemption, interest rate, stated percentage			7.00%
Membership interests of VIE subject to mandatory redemption, amount, current	$ 2	$ 2

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Benefit Plans Fair Value Measurements (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended																																																																																																																																																																																																	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014 Fair Value, Inputs, Level 1	Sep. 30, 2013 Fair Value, Inputs, Level 1	Sep. 30, 2014 Fair Value, Inputs, Level 2	Sep. 30, 2013 Fair Value, Inputs, Level 2	Sep. 30, 2014 Fair Value, Inputs, Level 3	Sep. 30, 2013 Fair Value, Inputs, Level 3	Sep. 30, 2012 Fair Value, Inputs, Level 3	Sep. 30, 2014 Equity securities	Sep. 30, 2013 Equity securities	Sep. 30, 2014 Equity securities Fair Value, Inputs, Level 1	Sep. 30, 2013 Equity securities Fair Value, Inputs, Level 1	Sep. 30, 2014 Equity securities Fair Value, Inputs, Level 2	Sep. 30, 2013 Equity securities Fair Value, Inputs, Level 2	Sep. 30, 2014 Equity securities Fair Value, Inputs, Level 3	Sep. 30, 2013 Equity securities Fair Value, Inputs, Level 3	Sep. 30, 2014 Preferred securities [Member]	Sep. 30, 2013 Preferred securities [Member]	Sep. 30, 2014 Preferred securities [Member] Fair Value, Inputs, Level 1	Sep. 30, 2013 Preferred securities [Member] Fair Value, Inputs, Level 1	Sep. 30, 2014 Preferred securities [Member] Fair Value, Inputs, Level 2	Sep. 30, 2013 Preferred securities [Member] Fair Value, Inputs, Level 2	Sep. 30, 2014 Preferred securities [Member] Fair Value, Inputs, Level 3	Sep. 30, 2013 Preferred securities [Member] Fair Value, Inputs, Level 3	Sep. 30, 2014 Corporate debt securities	Sep. 30, 2013 Corporate debt securities	Sep. 30, 2014 Corporate debt securities Fair Value, Inputs, Level 1	Sep. 30, 2013 Corporate debt securities Fair Value, Inputs, Level 1	Sep. 30, 2014 Corporate debt securities Fair Value, Inputs, Level 2	Sep. 30, 2013 Corporate debt securities Fair Value, Inputs, Level 2	Sep. 30, 2014 Corporate debt securities Fair Value, Inputs, Level 3	Sep. 30, 2013 Corporate debt securities Fair Value, Inputs, Level 3	Sep. 30, 2014 Residential mortgage-backed securities	Sep. 30, 2013 Residential mortgage-backed securities	Sep. 30, 2014 Residential mortgage-backed securities Fair Value, Inputs, Level 1	Sep. 30, 2013 Residential mortgage-backed securities Fair Value, Inputs, Level 1	Sep. 30, 2014 Residential mortgage-backed securities Fair Value, Inputs, Level 2	Sep. 30, 2013 Residential mortgage-backed securities Fair Value, Inputs, Level 2	Sep. 30, 2014 Residential mortgage-backed securities Fair Value, Inputs, Level 3	Sep. 30, 2013 Residential mortgage-backed securities Fair Value, Inputs, Level 3	Sep. 30, 2014 Debt securities issued by U.S. Treasury and other U.S. government agencies	Sep. 30, 2013 Debt securities issued by U.S. Treasury and other U.S. government agencies	Sep. 30, 2014 Debt securities issued by U.S. Treasury and other U.S. government agencies Fair Value, Inputs, Level 1	Sep. 30, 2013 Debt securities issued by U.S. Treasury and other U.S. government agencies Fair Value, Inputs, Level 1	Sep. 30, 2014 Debt securities issued by U.S. Treasury and other U.S. government agencies Fair Value, Inputs, Level 2	Sep. 30, 2013 Debt securities issued by U.S. Treasury and other U.S. government agencies Fair Value, Inputs, Level 2	Sep. 30, 2014 Debt securities issued by U.S. Treasury and other U.S. government agencies Fair Value, Inputs, Level 3	Sep. 30, 2013 Debt securities issued by U.S. Treasury and other U.S. government agencies Fair Value, Inputs, Level 3	Sep. 30, 2014 Debt securities issued by foreign governments	Sep. 30, 2013 Debt securities issued by foreign governments	Sep. 30, 2014 Debt securities issued by foreign governments Fair Value, Inputs, Level 1	Sep. 30, 2013 Debt securities issued by foreign governments Fair Value, Inputs, Level 1	Sep. 30, 2014 Debt securities issued by foreign governments Fair Value, Inputs, Level 2	Sep. 30, 2013 Debt securities issued by foreign governments Fair Value, Inputs, Level 2	Sep. 30, 2014 Debt securities issued by foreign governments Fair Value, Inputs, Level 3	Sep. 30, 2013 Debt securities issued by foreign governments Fair Value, Inputs, Level 3	Sep. 30, 2014 Asset-backed securities	Sep. 30, 2013 Asset-backed securities	Sep. 30, 2014 Asset-backed securities Fair Value, Inputs, Level 1	Sep. 30, 2013 Asset-backed securities Fair Value, Inputs, Level 1	Sep. 30, 2014 Asset-backed securities Fair Value, Inputs, Level 2	Sep. 30, 2013 Asset-backed securities Fair Value, Inputs, Level 2	Sep. 30, 2014 Asset-backed securities Fair Value, Inputs, Level 3	Sep. 30, 2013 Asset-backed securities Fair Value, Inputs, Level 3	Sep. 30, 2014 Debt securities issued by state/local governments	Sep. 30, 2013 Debt securities issued by state/local governments	Sep. 30, 2014 Debt securities issued by state/local governments Fair Value, Inputs, Level 1	Sep. 30, 2013 Debt securities issued by state/local governments Fair Value, Inputs, Level 1	Sep. 30, 2014 Debt securities issued by state/local governments Fair Value, Inputs, Level 2	Sep. 30, 2013 Debt securities issued by state/local governments Fair Value, Inputs, Level 2	Sep. 30, 2014 Debt securities issued by state/local governments Fair Value, Inputs, Level 3	Sep. 30, 2013 Debt securities issued by state/local governments Fair Value, Inputs, Level 3	Sep. 30, 2014 Commercial mortgage-backed securities	Sep. 30, 2013 Commercial mortgage-backed securities	Sep. 30, 2014 Commercial mortgage-backed securities Fair Value, Inputs, Level 1	Sep. 30, 2013 Commercial mortgage-backed securities Fair Value, Inputs, Level 1	Sep. 30, 2014 Commercial mortgage-backed securities Fair Value, Inputs, Level 2	Sep. 30, 2013 Commercial mortgage-backed securities Fair Value, Inputs, Level 2	Sep. 30, 2014 Commercial mortgage-backed securities Fair Value, Inputs, Level 3	Sep. 30, 2013 Commercial mortgage-backed securities Fair Value, Inputs, Level 3	Sep. 30, 2014 Equity security commingled funds	Sep. 30, 2013 Equity security commingled funds	Sep. 30, 2014 Equity security commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2013 Equity security commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Equity security commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2013 Equity security commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Equity security commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2013 Equity security commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Debt security commingled funds	Sep. 30, 2013 Debt security commingled funds	Sep. 30, 2014 Debt security commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2013 Debt security commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Debt security commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2013 Debt security commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Debt security commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2013 Debt security commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Commodity commingled funds	Sep. 30, 2014 Commodity commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Commodity commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Commodity commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Blended security commingled funds	Sep. 30, 2013 Blended security commingled funds	Sep. 30, 2014 Blended security commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2013 Blended security commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Blended security commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2013 Blended security commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Blended security commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2013 Blended security commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Institutional mutual funds	Sep. 30, 2013 Institutional mutual funds	Sep. 30, 2014 Institutional mutual funds Fair Value, Inputs, Level 1	Sep. 30, 2013 Institutional mutual funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Institutional mutual funds Fair Value, Inputs, Level 2	Sep. 30, 2013 Institutional mutual funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Institutional mutual funds Fair Value, Inputs, Level 3	Sep. 30, 2013 Institutional mutual funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Cash and cash equivalents	Sep. 30, 2013 Cash and cash equivalents	Sep. 30, 2014 Cash and cash equivalents Fair Value, Inputs, Level 1	Sep. 30, 2013 Cash and cash equivalents Fair Value, Inputs, Level 1	Sep. 30, 2014 Cash and cash equivalents Fair Value, Inputs, Level 2	Sep. 30, 2013 Cash and cash equivalents Fair Value, Inputs, Level 2	Sep. 30, 2014 Cash and cash equivalents Fair Value, Inputs, Level 3	Sep. 30, 2013 Cash and cash equivalents Fair Value, Inputs, Level 3	Sep. 30, 2014 Certificates of deposit	Sep. 30, 2014 Certificates of deposit Fair Value, Inputs, Level 1	Sep. 30, 2014 Certificates of deposit Fair Value, Inputs, Level 2	Sep. 30, 2014 Certificates of deposit Fair Value, Inputs, Level 3	Sep. 30, 2014 Private equity funds	Sep. 30, 2013 Private equity funds	Sep. 30, 2014 Private equity funds Fair Value, Inputs, Level 1	Sep. 30, 2013 Private equity funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Private equity funds Fair Value, Inputs, Level 2	Sep. 30, 2013 Private equity funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Private equity funds Fair Value, Inputs, Level 3	Sep. 30, 2013 Private equity funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Private real estate funds	Sep. 30, 2013 Private real estate funds	Sep. 30, 2014 Private real estate funds Fair Value, Inputs, Level 1	Sep. 30, 2013 Private real estate funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Private real estate funds Fair Value, Inputs, Level 2	Sep. 30, 2013 Private real estate funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Private real estate funds Fair Value, Inputs, Level 3	Sep. 30, 2013 Private real estate funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral	Sep. 30, 2013 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral	Sep. 30, 2014 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral Fair Value, Inputs, Level 1	Sep. 30, 2013 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral Fair Value, Inputs, Level 1	Sep. 30, 2014 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral Fair Value, Inputs, Level 2	Sep. 30, 2013 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral Fair Value, Inputs, Level 2	Sep. 30, 2014 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral Fair Value, Inputs, Level 3	Sep. 30, 2013 Treasury bills, U.S. Government notes and securities held as futures and other derivative collateral Fair Value, Inputs, Level 3	Sep. 30, 2014 Securities lending commingled funds	Sep. 30, 2013 Securities lending commingled funds	Sep. 30, 2014 Securities lending commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2013 Securities lending commingled funds Fair Value, Inputs, Level 1	Sep. 30, 2014 Securities lending commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2013 Securities lending commingled funds Fair Value, Inputs, Level 2	Sep. 30, 2014 Securities lending commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2013 Securities lending commingled funds Fair Value, Inputs, Level 3	Sep. 30, 2014 Purchased options	Sep. 30, 2013 Purchased options	Sep. 30, 2014 Purchased options Fair Value, Inputs, Level 1	Sep. 30, 2013 Purchased options Fair Value, Inputs, Level 1	Sep. 30, 2014 Purchased options Fair Value, Inputs, Level 2	Sep. 30, 2013 Purchased options Fair Value, Inputs, Level 2	Sep. 30, 2014 Purchased options Fair Value, Inputs, Level 3	Sep. 30, 2014 Foreign currency forward	Sep. 30, 2013 Foreign currency forward	Sep. 30, 2014 Foreign currency forward Fair Value, Inputs, Level 1	Sep. 30, 2013 Foreign currency forward Fair Value, Inputs, Level 1	Sep. 30, 2014 Foreign currency forward Fair Value, Inputs, Level 2	Sep. 30, 2013 Foreign currency forward Fair Value, Inputs, Level 2	Sep. 30, 2014 Foreign currency forward Fair Value, Inputs, Level 3	Sep. 30, 2013 Foreign currency forward Fair Value, Inputs, Level 3	Sep. 30, 2014 Futures	Sep. 30, 2014 Futures Fair Value, Inputs, Level 1	Sep. 30, 2014 Futures Fair Value, Inputs, Level 2	Sep. 30, 2014 Futures Fair Value, Inputs, Level 3	Sep. 30, 2014 Written option obligations	Sep. 30, 2013 Written option obligations	Sep. 30, 2014 Written option obligations Fair Value, Inputs, Level 1	Sep. 30, 2013 Written option obligations Fair Value, Inputs, Level 1	Sep. 30, 2014 Written option obligations Fair Value, Inputs, Level 2	Sep. 30, 2013 Written option obligations Fair Value, Inputs, Level 2	Sep. 30, 2014 Written option obligations Fair Value, Inputs, Level 3	Sep. 30, 2013 Written option obligations Fair Value, Inputs, Level 3	Sep. 30, 2013 Credit default swaps	Sep. 30, 2013 Credit default swaps Fair Value, Inputs, Level 1	Sep. 30, 2013 Credit default swaps Fair Value, Inputs, Level 2	Sep. 30, 2013 Credit default swaps Fair Value, Inputs, Level 3	Sep. 30, 2014 Minimum Number_of_extensions Years	Sep. 30, 2014 Maximum Years Number_of_extensions
Defined Benefit Plan Disclosure
Fair value of gross plan assets	$ 7,600	[1],[2]	$ 7,363	$ 1,804	$ 1,855	$ 5,148	$ 4,852	$ 648	$ 656	$ 633	$ 1,669	$ 1,689	$ 1,668	$ 1,686	$ 0	$ 0	$ 1	$ 3	$ 37	$ 22	$ 5	$ 17	$ 32	$ 0	$ 0	$ 5	$ 1,326	$ 1,352	$ 0	$ 0	$ 1,304	$ 1,334	$ 22	$ 18	$ 204	$ 355	$ 0	$ 0	$ 201	$ 352	$ 3	$ 3	$ 93	$ 113	$ 93	$ 113	$ 0	$ 0	$ 0	$ 0	$ 225	$ 31	$ 0	$ 0	$ 218	$ 30	$ 7	$ 1	$ 176	$ 120	$ 0	$ 0	$ 147	$ 110	$ 29	$ 10	$ 30	$ 36	$ 0	$ 0	$ 29	$ 36	$ 1	$ 0	$ 23	$ 21	$ 0	$ 0	$ 20	$ 18	$ 3	$ 3	$ 1,106	$ 1,182	$ 0	$ 0	$ 1,106	$ 1,182	$ 0	$ 0	$ 661	$ 786	$ 0	$ 0	$ 661	$ 786	$ 0	$ 0	$ 332	$ 0	$ 332	$ 0	$ 228	$ 263	$ 0	$ 0	$ 228	$ 263	$ 0	$ 0	$ 28	$ 26	$ 28	$ 26	$ 0	$ 0	$ 0	$ 0	$ 464	$ 395	$ 0	$ 1	$ 464	$ 394	$ 0	$ 0	$ 19	$ 0	$ 19	$ 0	$ 481	$ 528	$ 0	$ 0	$ 0	$ 0	$ 481	$ 528	$ 435	$ 382	$ 0	$ 0	$ 334	$ 297	$ 101	$ 85	$ 35	$ 39	$ 10	$ 8	$ 25	$ 31	$ 0	$ 0	$ 2	$ 3	$ 0	$ 0	$ 2	$ 3	$ 0	$ 0	$ 18	$ 6	$ 0	$ 0	$ 18	$ 6	$ 0	$ 8	$ 6	$ 0	$ 0	$ 8	$ 6	$ 0	$ 0						$ 4		$ 4		$ 0		$ 0	$ 4	$ 0	$ 4
Derivative liabilities	26	[1],[3]	8	11	0	15	8	0	0																																																																																																																																																																	8	6	0	0	8	6	0	0	11	11	0	0	7	1	0	0	7	1	0	0	1	0	1	0
Net payables	65		131
Payables for collateral on loaned securities	$ 2		$ 3
Number of years partnerships in private equity generally continue																																																																																																																																																																																																		10	12
Number of one year extensions for partnerships in private equity																																																																																																																																																																																																		3	4
Voting percentage required to desolve partnership in private equity	80.00%

[1] Excludes approximately $65 million in net payables associated with security purchases and sales and various other payables.

[2] Excludes a $3 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

[3] Excludes a $2 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

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Summary of Significant Accounting Policies

12 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

General

The Tennessee Valley Authority ("TVA") is a corporate agency and instrumentality of the United States that was created in 1933 by legislation enacted by the United States ("U.S.") Congress 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 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 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 over nine 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 ("Bonds").  Although TVA does not currently receive congressional appropriations, it is required to make annual payments to the U.S. Treasury as a return on the government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment").  In the 1998 Energy and Water Development Appropriations Act, Congress directed TVA to fund essential stewardship activities related to its management of the Tennessee River system and nonpower or stewardship properties with power revenues in the event that there were insufficient appropriations or other available funds to pay for such activities in any fiscal year.  Congress has not provided any appropriations to TVA to fund such activities since 1999.  Consequently, during 2000, TVA began paying for essential stewardship activities primarily with power revenues, with the remainder funded with user fees and other forms of revenues derived in connection with those activities.  The activities related to stewardship properties do not meet the criteria of an operating segment under accounting principles generally accepted in the United States of America ("GAAP").  Accordingly, these assets and properties are included as part of the power program, TVA's only operating segment.

Power rates are established by the TVA Board of Directors ("TVA Board") as authorized by the Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (as amended, 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 power system assets, retirement of outstanding Bonds in advance of maturity, additional reduction of the Power Program Appropriation Investment, and other purposes connected with TVA's power business.  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 (2014, 2013, 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.  In view of demand for electricity and the level of competition, 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 and variable interest entities of which TVA is determined to be the primary beneficiary. See Note 9. 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 reclassifications have been made to the Consolidated Statement of Cash Flows for the year ended September 30, 2014, in the Cash flows from operating activities section as $47 million and $5 million previously reported in Environmental cleanup costs — Kingston ash spill for the years ended September 30, 2013 and 2012, respectively, were reclassified to Insurance recoveries.    

Cash and Cash Equivalents

Cash includes cash on hand and non-interest bearing cash and deposit accounts. All highly liquid investments with original maturities of three months or less are considered cash equivalents.

Restricted Cash and Investments

Restricted cash and investments reflect amounts related to collateral posted with TVA by a swap counterparty.

Allowance for Uncollectible Accounts

The allowance for uncollectible accounts reflects TVA's estimate of probable losses inherent in its accounts and loans receivable balances.  TVA determines the allowance based on known accounts, historical experience, and other currently available information including events such as customer bankruptcy and/or a customer 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 $1 million at September 30, 2014, and 2013, for accounts receivable.  Additionally, loans receivable of $92 million and $73 million at September 30, 2014, and 2013, respectively, were included in Accounts receivable, net and Other long-term assets and reported net of allowances for uncollectible accounts of $9 million and $10 million at September 30, 2014, and 2013, respectively.

The following table contains information about TVA’s current estimates related to uncollectible accounts.

Allowance for Uncollectible Accounts (in millions)
Description	Balance at beginning of year		Additions charged to expense		Deductions			Balance at end of year
For the year ended September 30, 2014
Allowance for uncollectible accounts
Receivables	$	1	$	1	$	(1	)	$	1
Loans	10		—		(1		)	9
Total allowances deducted from assets	$	11	$	1	$	(2	)	$	10
For the year ended September 30, 2013
Allowance for uncollectible accounts
Receivables	$	7	$	—	$	(6	)	$	1
Loans	12		—		(2		)	10
Total allowances deducted from assets	$	19	$	—	$	(8	)	$	11
For the year ended September 30, 2012
Allowance for uncollectible accounts
Receivables	$	1	$	6	$	—		$	7
Loans	11		1		—			12
Total allowances deducted from assets	$	12	$	7	$	—		$	19

Revenues

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 six 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.) 

From time to time TVA transfers fiber optic capacity on TVA’s network to telecommunications service carriers and local power company customers of TVA ("LPCs").  These transactions are structured as indefeasible rights of use ("IRUs"), which are the exclusive right to use a specified amount of fiber optic capacity for a specified term.  TVA accounts for the consideration received on transfers of fiber optic capacity for cash and on all of the other elements deliverable under an IRU as revenue ratably over the term of the agreement.  TVA does not recognize revenue on any contemporaneous exchanges of its fiber optic capacity for an IRU of fiber optic capacity of the counterparty to the exchange.

TVA engages in a wide array of arrangements in addition to power sales.  TVA records revenue when it is realized or realizable and earned when all of the following criteria are met: persuasive evidence of an arrangement exists; delivery has occurred or services have been rendered; the price or fee is fixed or determinable; and collectability is reasonably assured. Revenues from activities related to TVA’s overall mission are recorded as other operating revenue versus those that are not related to the overall mission, which are recorded in Other income (expense), net.

Inventories

CertainFuel, Materials, and Supplies.  Coal, oil, limestone, tire-based fuel inventories, and 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. Natural gas inventories are valued using an average cost method, and a new average cost is computed monthly.

Allowance for Inventory Obsolescence.  TVA reviews material 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.  Based on the estimated value of the inventory, TVA adjusts its allowance for inventory obsolescence.

Emission Allowances.  TVA has emission allowances for sulfur dioxide ("SO₂")and nitrogen oxides ("NO_x") which are accounted for as inventory.  The average cost of allowances used each month is charged to operating expense based on tons of SO₂ and NO_x emitted during the respective compliance periods.  Allowances granted to TVA by the Environmental Protection Agency ("EPA") are recorded at zero cost.

Property, Plant, and Equipment, and Depreciation

Property, Plant, and Equipment. Additions to plant are recorded at cost, which includes direct and indirect costs and an allowance for funds used during construction ("AFUDC").  The cost of current repairs and minor replacements is charged to operating expense.  Nuclear fuel inventories, which are included in Property, plant, and equipment, are 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.

Depreciation. TVA accounts for depreciation of its properties using the composite depreciation convention of accounting.  Accordingly, the original cost of property retired is charged to accumulated depreciation. Except as described below, depreciation is generally computed on a straight-line basis over the estimated service lives of the various classes of assets. Depreciation expense for the years ended September 30, 2014, 2013, and 2012 was $1.6 billion, $1.4 billion, and $1.7 billion, respectively. Depreciation expense expressed as a percentage of the average annual depreciable completed plant was 3.42 percent for 2014, 3.12 percent for 2013, and 3.78 percent for 2012.  Average depreciation rates by asset class are as follows:

Property, Plant, and Equipment Depreciation Rates At September 30 (percent)
	2014	2013	2012
Asset Class
Nuclear	2.90	2.86	2.71
Coal-Fired	4.37	3.47	5.65
Hydroelectric	1.44	1.30	1.35
Gas and oil-fired	3.23	3.21	3.67
Transmission	2.76	2.76	2.99
Other	8.40	8.14	8.10

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 (collectively, the "Environmental Agreements”).  See Note 21 — Legal Proceedings — Environmental Agreements.  Under the Environmental Agreements, TVA committed, among other things, to retire, on a phased schedule, 18 coal-fired units. 

Consistent with the Environmental Agreements, Units 1 and 2 at John Sevier Fossil Plant ("John Sevier") were retired

on December 31, 2012, and Units 3 and 4 were idled on December 31, 2012 and subsequently retired on June 25, 2014. Units 3 and 5 at Widows Creek Fossil Plant ("Widows Creek") were retired on July 31, 2013, and Units 1, 2, 4, and 6 at Widows Creek were retired on July 31, 2014. On October 1, 2013, Colbert Fossil Plant ("Colbert") Unit 5 and Johnsonville Fossil Plant ("Johnsonville") Units 5, 6, 9, and 10 were idled. In addition, Units 7 and 8 at Johnsonville were idled March 1, 2012, and Unit 10 at Shawnee Fossil Plant ("Shawnee") was idled in October 2010 and subsequently retired on June 30, 2014.

On November 14, 2013, the TVA Board of Directors (the "TVA Board") approved the retirement of Colbert Units 1-5 no later than June 30, 2016, and the retirement of Widows Creek Unit 8. Additionally, the TVA Board approved the retirement of Paradise Fossil Plant ("Paradise") Units 1 and 2 upon the completion of a natural gas-fired plant at the Paradise location.

On August 21, 2014, the TVA Board approved the retirement of Allen Fossil Plant ("Allen") Units 1-3 upon the completion of a natural gas-fired plant at the Allen location.

Depreciation rates are adjusted to reflect current assumptions so that the units will be fully depreciated by the applicable idle dates.  As a result of TVA's decision to idle or retire units, TVA recognized $206 million and $49 million in accelerated depreciation expense related to the units during the years ended September 30, 2014, and 2013, respectively.

Capital Lease Agreements.  Property, plant, and equipment also includes assets recorded under capital lease agreements. These primarily consist of a natural gas lateral pipeline, power production facilities, water treatment assets, and land of $102 million and $42 million at September 30, 2014 and 2013, respectively, and fuel fabrication and blending facilities of $5 million at September 30, 2013. There were no obligations for fuel fabrication and blending facilities at September 30, 2014. Amortization expense related to capital leases is included in Depreciation and amortization in TVA’s statements of operations.

Allowance for Funds Used During Construction.  AFUDC capitalized during the year ended September 30, 2014, was $175 million, as compared to $168 million capitalized during the year ended September 30, 2013.  TVA capitalizes interest as AFUDC, based on the average interest rate of TVA’s outstanding debt.  The allowance is applicable to construction in progress related to projects with (1) an expected total project cost of $1.0 billion or more, and (2) an estimated construction period of at least three years in duration. During 2012 and 2011, TVA also included certain nuclear fuel inventories in the calculation of the allowance. During 2012, the TVA Board approved a change in the AFUDC methodology which removed the inclusion of nuclear fuel from the AFUDC calculation effective October 1, 2012. The accumulated balance of costs, which is used to calculate AFUDC, averaged approximately $3.3 billion for the year ended September 30, 2014. Subsequent to August 31, 2013, the accumulated balance of costs for Bellefonte Nuclear Plant ("Bellefonte") were removed from this calculation.

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 amortized primarily over five years.  At September 30, 2014 and 2013, unamortized computer software costs totaled $22 million and $5 million, respectively.  Amortization expense related to capitalized computer software costs was $31 million for each of 2014, 2013, and 2012.  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, 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 Board approval, reclassified as a regulatory asset.

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 reclamation.  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.  Any accretion or depreciation expense related to these liabilities and assets is charged to a regulatory asset.  See Note 8 — Nuclear Decommissioning Costs and Non-Nuclear Decommissioning Costs andNote 12.

Blended Low-Enriched Uranium Program

Under the blended low-enriched uranium ("BLEU") program, TVA, the 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.  This blended nuclear fuel was first loaded in a Browns Ferry Nuclear Plant ("Browns Ferry") reactor in 2005 and is expected to continue to be used to reload the Browns Ferry reactors through at least 2016. BLEU fuel was loaded into Sequoyah Nuclear Plant ("Sequoyah") Unit 2 three times but is not expected to be used in the Sequoyah reactors in the future.

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.  The third-party fuel processors own the conversion and processing facilities and will retain title to all land, property, plant, and equipment used in the BLEU fuel program.  Over the life of the program, TVA projects that the DOE’s share of savings generated by TVA’s use of this blended nuclear fuel could result in payments to the DOE of as much as $160 million.  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.  During 2009, the DOE and TVA agreed that this obligation would be offset by amounts that the DOE expects to owe TVA in the future for certain decommissioning costs that TVA will pay on the DOE’s behalf.  Accordingly, TVA will remit the BLEU fuel savings amounts to the DOE, only after those future decommissioning costs have been offset against TVA’s obligation to the DOE. At September 30, 2014, TVA had paid out approximately $101 million for this program, and the obligation recorded was $16 million.

Investment Funds

Investment funds consist primarily of trust funds designated to fund nuclear decommissioning requirements (see Note 21 — Contingencies — Decommissioning Costs), non-nuclear AROs (see Note 8 — Non-Nuclear Decommissioning Costs), the Supplemental Executive Retirement Plan ("SERP") (see Note 20 — Overview of Plans and Benefits — Supplemental Executive Retirement Plan), and the Long-Term Deferred Compensation Plan ("LTDCP"). Nuclear decommissioning funds and SERP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity market performance, while asset retirement and LTDCP funds are invested in portfolios of securities generally designed to achieve a return in line with overall equity and debt market performance. The nuclear decommissioning funds, asset retirement funds, SERP funds, and LTDCP funds are all classified as trading.

Energy Prepayment Obligations and Discounts on Sales

During 2002, TVA introduced an energy prepayment program, the discounted energy units ("DEU") program.  Under this program, TVA LPCs could purchase DEUs generally in $1 million increments, and each DEU entitles the purchaser to a $.025/kilowatt-hour discount on a specified quantity of firm power over a period of years (5, 10, 15, or 20) for each kilowatt-hour in the prepaid block.  The remainder of the price of the kilowatt-hours delivered to the LPC is due upon billing.  TVA’s DEU program allowed LPCs to use cash on hand to prepay TVA for some of their power needs, providing funding to TVA and a savings to LPCs in the form of a discount on future purchases.  The LPC receives a discount on a specified volume of firm energy purchased.  The supplement to the power contract specifies the discount rate (2.5 cents per kilowatt-hour), the monthly block of kilowatt-hours to which the discount applies, the number of years (term), and contingencies upon contract termination.

TVA has not offered the DEU program since the end of 2004.  Total sales for the program since inception have been approximately $55 million.  TVA accounted for the prepayment proceeds as unearned revenue and reported the obligations to deliver power as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2013 Consolidated Balance Sheet. There were no outstanding DEU liabilities at September 30, 2014.

TVA recognizes revenue as electricity is delivered to LPCs, based on the ratio of units of kilowatt-hours delivered to total units of kilowatt-hours under contract.  At September 30, 2014, all of TVA’s obligations under the DEU program had expired, and the entire approximately $55 million had been applied against power billings on a cumulative basis during the life of the program, of which less than $1 million was recognized as noncash revenue during 2014.  Approximately $2 million and $5 million were applied against power billings during 2013 and 2012, respectively.

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 is reporting the obligation to deliver power under this arrangement as Energy prepayment obligations and Current portion of energy prepayment obligations on the September 30, 2014 and 2013 Consolidated Balance Sheets.  TVA expects to recognize approximately $100 million of noncash revenue in each year of the arrangement as electricity is delivered to MLGW based on the ratio of units of kilowatt-hours delivered to total units of kilowatt-hours under contract.  At September 30, 2014, approximately $1.1 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 during each of 2014, 2013, and 2012.

Discounts, which are recorded as a reduction to electricity sales, for both programs amounted to $46 million for the year ended September 30, 2014, and $47 million for each of the years ended September 30, 2013, and 2012.

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 balance sheets.

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.

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.

TVA purchases nuclear liability insurance, nuclear property, decommissioning, and decontamination insurance, and nuclear accidental outage insurance.  See Note 21— Contingencies — Nuclear Insurance.

TVA purchases excess liability insurance for aviation, auto, marine, and general liability exposures.  TVA purchases property insurance for certain conventional (non-nuclear) assets.  

The insurance policies are subject to the terms and conditions of the specific policy.  Each of the insurance policies purchased contains deductibles or self-insured retentions.  TVA recovers the costs of losses 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

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 and then adds 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 statements of operations as they are incurred except for the recording of certain regulatory assets for retirement and removal costs.

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CONSOLIDATED BALANCE SHEETS (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Current assets
Cash and cash equivalents	$ 500	$ 1,602
Restricted cash and investments	19	33
Accounts receivable, net	1,676	1,567
Inventories, net	1,056	1,091
Regulatory assets	481	561
Other current assets	56	52
Total current assets	3,788	4,906
Property, plant, and equipment
Completed plant	47,564	47,073
Less accumulated depreciation	(24,589)	(23,157)
Net completed plant	22,975	23,916
Construction in progress	5,951	4,704
Nuclear fuel	1,322	1,256
Capital leases	102	47
Total property, plant, and equipment, net	30,350	29,923
Investment funds	1,981	1,701
Regulatory and other long-term assets
Regulatory assets	8,994	9,131
Other long-term assets	483	445
Total regulatory and other long-term assets	9,477	9,576
Total assets	45,596	46,106
Current liabilities
Accounts payable and accrued liabilities	2,029	1,627
Environmental cleanup costs - Kingston ash spill	21	102
Accrued interest	380	378
Current portion of leaseback obligations	75	69
Current portion of energy prepayment obligations	100	100
Regulatory liabilities	184	212
Short-term debt, net	596	2,432
Current maturities of power bonds	1,032	32
Current maturities of long-term debt of variable interest entities	32	30
Total current liabilities	4,449	4,982
Other liabilities
Post-retirement and post-employment benefit obligations	5,839	5,348
Asset retirement obligations	3,089	3,472
Other long-term liabilities	1,962	1,861
Leaseback obligations	616	692
Energy prepayment obligations	310	410
Environmental cleanup costs - Kingston ash spill	0	67
Regulatory liabilities	0	1
Total other liabilities	11,816	11,851
Long-term debt, net
Long-term power bonds, net	21,948	22,315
Long-term debt of variable interest entities	1,279	1,311
Total long-term debt, net	23,227	23,626
Total liabilities	39,492	40,459
Commitments and contingencies (Note 20)
Proprietary capital
Power program appropriation investment	258	268
Power program retained earnings	5,240	4,767
Total power program proprietary capital	5,498	5,035
Nonpower programs appropriation investment, net	601	609
Accumulated other comprehensive income (loss)	5	3
Total proprietary capital	6,104	5,647
Total liabilities and proprietary capital	$ 45,596	$ 46,106

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Other Long-Term Liabilities

12 Months Ended

Sep. 30, 2014

Other Liabilities, Noncurrent [Abstract]

Other Long-Term Liabilities

Other Long-Term Liabilities

Other long-term liabilities consist primarily of liabilities related to certain derivative agreements as well as liabilities under agreements related to compliance with certain environmental regulations (see Note 21 — Legal Proceedings — Environmental Agreements). The table below summarizes the types and amounts of Other long-term liabilities:

Other Long-Term Liabilities At September 30
	2014		2013
Interest rate swap liabilities	$	1,348	$	1,199
Environmental Agreements liability	108		190
EnergyRight® financing obligation	152		149
Membership interests of VIE subject to mandatory redemption	37		38
Commodity contract derivative liabilities	17		35
Commodity swap derivative liabilities	14		36
Currency swap liabilities	15		15
Other	271		199
Total other long-term liabilities	$	1,962	$	1,861

EnergyRight^® Purchase Obligation. TVA purchases certain loans receivable from its LPCs in association with the EnergyRight^® Solutions program. 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. Given this continuing involvement, TVA accounts for the transfer of the loans receivable as secured borrowings. 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, 2014 and September 30, 2013, the carrying amount of the financing obligation reported in Accounts payable and accrued liabilities was approximately $38 million and $37 million, respectively. See Note 7 for information regarding the associated loans receivable.

Membership Interests of VIE Subject to Mandatory Redemption. On August 9, 2013, SCCG issued 100 percent of its membership interests to SHLLC for a total of $40 million. The membership interests in SCCG are mandatorily redeemable pursuant to a schedule of payments that indicates the amount of each payment and the corresponding dates on which each payment is due. The schedule requires SCCG to make semi-annual payments to SHLLC sufficient to provide returns on, as well as returns of, capital until the investment has been repaid in full, including a $4 million balloon payment as part of the final disbursement which is due on August 15, 2033. The return on capital includes the Seven States Return. These payments provide a return on investment to SHLLC of 7.0 percent, which is reflected as interest expense in the consolidated statements of operations. As of September 30, 2014 and September 30, 2013, the carrying amount of the Membership interests of VIE subject to mandatory redemption was $39 million and $40 million, respectively. As of September 30, 2014 and 2013, $2 million of this was current and included in Accounts payable and accrued liabilities.

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.

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Benefit Plans Expected Amortization of Regulatory Assets in Next Fiscal Year (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014
Defined Benefit Plan Disclosure
Prior service cost (credit)	$ (27)
Net actuarial loss	285
Pension Benefits
Defined Benefit Plan Disclosure
Prior service cost (credit)	(21)
Net actuarial loss	277
Other Post-retirement Benefits
Defined Benefit Plan Disclosure
Prior service cost (credit)	(6)
Net actuarial loss	$ 8

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Proprietary Capital Proprietary Capital (Details) (USD $)	3 Months Ended								12 Months Ended
	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Appropriation Investment
Amount of appropriation investment that must be repaid	$ 1,000,000,000								$ 1,000,000,000
Remaining appropriation investment	258,000,000								258,000,000
Balance at beginning of year				5,647,000,000				5,326,000,000	5,647,000,000	5,326,000,000	5,229,000,000
Net income (loss)	322,000,000	(81,000,000)	295,000,000	(67,000,000)	474,000,000	(12,000,000)	54,000,000	(245,000,000)	469,000,000	271,000,000	60,000,000
Return of power program appropriation investment									10,000,000	20,000,000	20,000,000
Return on power program appropriation investment									4,000,000	7,000,000	7,000,000
Balance at end of year	6,104,000,000				5,647,000,000				6,104,000,000	5,647,000,000	5,326,000,000
Net proprietary capital at September 30	6,104,000,000				5,647,000,000				6,104,000,000	5,647,000,000
Computed average interest rate payable	1.97%				2.10%				1.97%	2.10%	2.33%
Nonpower Programs Appropriation Investment
Appropriation Investment
Balance at beginning of year				4,351,000,000				4,351,000,000	4,351,000,000	4,351,000,000
Return of power program appropriation investment									0	0
Balance at end of year	4,351,000,000				4,351,000,000				4,351,000,000	4,351,000,000
Power Program Appropriation Investment
Appropriation Investment
Balance at beginning of year				268,000,000				288,000,000	268,000,000	288,000,000	308,000,000
Net income (loss)									0	0	0
Return of power program appropriation investment									10,000,000	20,000,000	20,000,000
Return on power program appropriation investment									0	0	0
Balance at end of year	258,000,000				268,000,000				258,000,000	268,000,000	288,000,000
Power Program Retained Earnings
Appropriation Investment
Balance at beginning of year				4,767,000,000				4,492,000,000	4,767,000,000	4,492,000,000	4,429,000,000
Net income (loss)									477,000,000	282,000,000	70,000,000
Return of power program appropriation investment									0	0	0
Return on power program appropriation investment									4,000,000	7,000,000	7,000,000
Balance at end of year	5,240,000,000				4,767,000,000				5,240,000,000	4,767,000,000	4,492,000,000
Net proprietary capital at September 30	5,498,000,000				5,035,000,000				5,498,000,000	5,035,000,000
Nonpower Programs Retained Earnings
Appropriation Investment
Balance at beginning of year				(3,742,000,000)				(3,731,000,000)	(3,742,000,000)	(3,731,000,000)
Net income (loss)									(8,000,000)	(11,000,000)
Return on power program appropriation investment									0	0
Balance at end of year	(3,750,000,000)				(3,742,000,000)				(3,750,000,000)	(3,742,000,000)
Net proprietary capital at September 30	601,000,000				609,000,000				601,000,000	609,000,000
Power Program Appropriation Investment
Appropriation Investment
Return of power program appropriation investment									$ 10,000,000	$ 20,000,000

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Fair Value Measurements Fair Value Measurements - Fair Value Measurements Using Significant Unobservable Inputs (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Commodity contract derivatives	$ 1,000,000	$ 3,000,000
Commodity contract derivatives	97,000,000	144,000,000
Liabilities
Number of contracts	2	1
Fair Value Measurements
Amount of gain (loss) recognized in income	57,000,000
Private Partnerships
Fair Value Measurements
Balances at beginning of period	159,000,000	53,000,000
Purchases	39,000,000	101,000,000
Issuances	0	0
Sales	(9,000,000)	(4,000,000)
Settlements	0	0
Net unrealized gains (losses) deferred as regulatory assets and liabilities	25,000,000	9,000,000
Balances at end of period	214,000,000	159,000,000
Commodity Contract Derivatives
Fair Value Measurements
Balances at beginning of period	(140,000,000)	(267,000,000)
Purchases	0	0
Issuances	0	0
Sales	0	0
Settlements	33,000,000	0
Net unrealized gains (losses) deferred as regulatory assets and liabilities	11,000,000	127,000,000
Balances at end of period	(96,000,000)	(140,000,000)
Minimum
Assets
Fair value inputs, counterparty credit risk	2.00%
Fair value measurements tons per year	1,000,000,000	900,000,000
Price per ton	11.24	10.25
Liabilities
Fair value measurements tons per year	1,000,000,000	900,000,000
Price per ton	11.24	10.25
Maximum
Assets
Fair value inputs, counterparty credit risk	5.00%	21.00%
Fair value measurements tons per year	1,100,000,000	1,000,000,000
Price per ton	67.07	85.25
Liabilities
Fair value measurements tons per year	1,100,000,000	1,000,000,000
Price per ton	67.07	85.25
Fair Value, Inputs, Level 3
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Commodity contract derivatives	1,000,000	3,000,000
Commodity contract derivatives	$ 97,000,000	$ 143,000,000

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Commitments and Contingencies Commitments and Contingencies - Legal Proceedings (Details) (USD $)	12 Months Ended				1 Months Ended		12 Months Ended			1 Months Ended		12 Months Ended	1 Months Ended					3 Months Ended	1 Months Ended
	Dec. 31, 2010	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014 General	Apr. 30, 2011 Environmental Agreements Groups Agreements	Jun. 30, 2011 Environmental Agreements Units Megawatts	Sep. 30, 2014 Kingston Ash Spill Legal_actions	Jun. 30, 2014 Kingston Ash Spill Legal_actions	Jun. 30, 2010 Kingston Ash Spill	Sep. 30, 2010 Case Involving Tennessee Valley Authority Retirement System	Mar. 31, 2010 Case Involving Tennessee Valley Authority Retirement System People	Dec. 31, 2010 Case Involving Tennessee Valley Authority Retirement System	Jun. 30, 2012 Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage	Jul. 31, 2013 Administrative Proceedings Regarding Sequoyah U1 and U2 [Member] Legal_actions	May 31, 2013 Administrative Proceedings Regarding Sequoyah U1 and U2 [Member]	Aug. 31, 2011 Administrative Proceedings Regarding Bellefonte Units 3 and 4	Jun. 30, 2008 Administrative Proceedings Regarding Bellefonte Units 3 and 4 Legal_actions	Sep. 30, 2012 Administrative Proceedings Regarding Bellefonte Units 3 and 4	Nov. 30, 2009 Administrative Proceedings Regarding Watts Bar Nuclear Plant Unit 2 People Legal_actions	Dec. 31, 2011 Petitions Resulting from Japanese Nuclear Events Legal_actions	Aug. 31, 2011 Petitions Resulting from Japanese Nuclear Events Legal_actions	Sep. 30, 2014 Other long-term liabilities General	Sep. 30, 2014 Accounts payable and accrued liabilities General
Legal Proceedings
Accrual for Environmental Loss Contingencies, Gross		$ 15,000,000	$ 15,000,000
Legal loss contingency accrual				172,000,000																		108,000,000	64,000,000
Estimated range of losses low end of range				172,000,000
Estimated range of losses high end of range				173,000,000
Number of similar environmental agreements entered into					2
Number of environmental agreements entered into with the EPA					1
Number of environmental agreements entered into with Alabama, Kentucky, North Carolina, and Tennessee					1
Number of environmental agreements entered into with environmental advocacy groups					3
Number of units to be idled						18
Megawatts option 1						2,200
Megawatts option 2						3,500
Amount to be invested in certain environmental projects						290,000,000
Amount to be provided to fund environmental projects						60,000,000
Amount to pay civil penalties						10,000,000
Number of lawsuits filed							78
Number of lawsuits dismissed								15
Loss Contingency, Claims Dismissed, Number							63
Number of active lawsuits							9
Payments for Legal Settlements							28,000,000
Civil penalty order issued June 1, 2010									12,000,000
Amount of civil penalty order satisfied							10,000,000
Credit against civil penalty order							2,000,000
Down payment on natural resource damages							$ 750,000
Number of participants that filed suit											8
Number of TVARS Board members											6
Number of Board Members Appointed											1
Number of defendants that filed a motion to dismiss											5
Retirement age of eligibility for cost of living adjustment before January 1, 2010	55											55
Retirement age of eligibility for cost of living adjustment after January 1, 2010	60											60
Number of days to file an ammended complaint										14 days
Number of years that spent fuel can be stored after a plant's license is terminated													60 years
Number of contentions submitted by BREDL BEST and MATRR															8
Opposed contentions															8
Number of petitioners with standing														1
Number of petitioners														3
Number of contentions dismissed														7					1
Number of contentions left														1			2
Number of admitted contentions submitted by BREDL and SACE																	4
Number of contentions submitted by BREDL and SACE																	20
Number of contentions no longer admitted																	2
Number of BREDL contentions																		1
Number of contentions admitted for hearing																			2
Number of SACE contentions																1			7
Number of other petitioners																			4
Number of contentions remaining																			1
Number of units at John Sevier Fossil		4
Units Affected by Paradise Case		2
Number of requests accepted by the NRC																				5
Number of separate petitions filed by the Natural Resources Defense Council																					12
Number of individual defendants											6
Remaining defendant											1

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DEI Document (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014
Document Information [Line Items]
Entity Registrant Name	Tennessee Valley Authority
Entity Central Index Key	0001376986
Current Fiscal Year End Date	--09-30
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Sep. 30, 2014
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding	0
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float	$ 0

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Asset Retirement Obligations

12 Months Ended

Sep. 30, 2014

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

During the year ended September 30, 2014, TVA's total ARO liability decreased $319 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. Prior to June 30, 2014, TVA based its decommissioning cost estimates on cost elements prescribed by the NRC to dismantle and decommission the radioactive portion of each site with the assumption that decommissioning would occur within the first seven years after plant shut down, which approximates the DECON method of decommissioning. The DECON method requires that radioactive contamination is 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. On June 30, 2014, TVA recorded a change in estimate based on site-specific decommissioning cost studies. Additionally, TVA determined it appropriate to reflect an increase in the probability that certain of its nuclear operating licenses will be extended and that there is a probability that it will be able to delay ultimate decommissioning activities under a SAFSTOR method of decommissioning. 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. As such, TVA ascribed probabilities to both the SAFSTOR and DECON methods of decommissioning in order to estimate its decommissioning obligation. Decommissioning cost studies will be updated for each of TVA’s nuclear units at least every five years.

Additionally, both the nuclear and non-nuclear liabilities were increased by periodic accretion. This was partially offset by coal ash area settlement projects that were conducted during the year ended September 30, 2014. The nuclear and non-nuclear accretion were deferred as regulatory assets, and $40 million of the related regulatory assets was amortized into expense as this amount was collected in rates.

Asset Retirement Obligation Activity
	Nuclear			Non-Nuclear			Total
Balance at September 30, 2012	$	2,208		$	1,081		$	3,289
Settlements (ash storage areas)	—			(37		)	(37		)
Change in estimate (ash storage areas)	66			—			66
Accretion (recorded to regulatory asset)	125			45			170
Balance at September 30, 2013	$	2,399		$	1,089		$	3,488
Settlements (ash storage areas)	—			(14		)	(14		)
Change in estimate as a result of nuclear site-specific studies	(472		)	—			(472		)
Change in estimate (ash storage areas)	—			(10		)	(10		)
Accretion (recorded to regulatory asset)	125			52			177
Balance at September 30, 2014	$	2,052		$	1,117		$	3,169		(1)

Note

(1) The current portion of ARO in the amount of $80 million is included in Accounts payable and accrued liabilities.

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivative Instruments That Receive Hedge Accounting Treatment (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Summary of Derivative Instruments That Receive Hedge Accounting Treatment
Net unrealized gain (loss) on future cash flow hedges	$ 4,000,000	$ 78,000,000	$ 99,000,000
Reclassification to earnings from cash flow hedges	(2,000,000)	(1,000,000)	(35,000,000)
Ineffective portion excluded from testing	0	0
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	$ 37,000,000

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Fair Value Measurements Fair Value Measurements - Fair Value Measurements (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013
Investments
Equity securities	$ 162		$ 151
Debt securities
U.S. government corporations and agencies	85		105
Corporate debt securities	290		255
Residential mortgage-backed securities	14		25
Commercial mortgage-backed securities	7		7
Collateralized debt obligations	29		10
Private partnerships	214		159
Commingled funds
Equity security commingled funds	943	[1]	741	[1]
Debt security commingled funds	237	[1]	248	[1]
Total investments	1,981		1,701
Currency swaps	0		28
Commodity contract derivatives	1		3
Commodity derivatives under FTP
Swap contracts	0		3
Total commodity derivatives under FTP	0		3
Total	1,982		1,735
Liabilities [Abstract]
Currency swaps	15		15
Interest rate swaps	1,348		1,199
Commodity contract derivatives	97		144
Commodity derivatives under FTP
Swap contracts	34		69
Total commodity derivatives under FTP	34		69
Total	1,494		1,427
Fair Value, Inputs, Level 1
Investments
Equity securities	162		151
Debt securities
U.S. government corporations and agencies	46		38
Corporate debt securities	0		0
Residential mortgage-backed securities	0		0
Commercial mortgage-backed securities	0		0
Collateralized debt obligations	0		0
Private partnerships	0		0
Commingled funds
Equity security commingled funds	40	[1]	0	[1]
Debt security commingled funds	61	[1]	0	[1]
Total investments	309		189
Currency swaps	0		0
Commodity contract derivatives	0		0
Commodity derivatives under FTP
Swap contracts	0		0
Total commodity derivatives under FTP	0		0
Total	309		189
Liabilities [Abstract]
Currency swaps	0		0
Interest rate swaps	0		0
Commodity contract derivatives	0		0
Commodity derivatives under FTP
Swap contracts	0		0
Total commodity derivatives under FTP	0		0
Total	0		0
Fair Value, Inputs, Level 2
Investments
Equity securities	0		0
Debt securities
U.S. government corporations and agencies	39		67
Corporate debt securities	290		255
Residential mortgage-backed securities	14		25
Commercial mortgage-backed securities	7		7
Collateralized debt obligations	29		10
Private partnerships	0		0
Commingled funds
Equity security commingled funds	903	[1]	741	[1]
Debt security commingled funds	176	[1]	248	[1]
Total investments	1,458		1,353
Currency swaps	0	[2]	28	[2]
Commodity contract derivatives	0		0
Commodity derivatives under FTP
Swap contracts	0		3
Total commodity derivatives under FTP	0		3
Total	1,458		1,384
Liabilities [Abstract]
Currency swaps	15		15
Interest rate swaps	1,348		1,199
Commodity contract derivatives	0		1
Commodity derivatives under FTP
Swap contracts	34		69
Total commodity derivatives under FTP	34		69
Total	1,397		1,284
Fair Value, Inputs, Level 3
Investments
Equity securities	0		0
Debt securities
U.S. government corporations and agencies	0		0
Corporate debt securities	0		0
Residential mortgage-backed securities	0		0
Commercial mortgage-backed securities	0		0
Collateralized debt obligations	0		0
Private partnerships	214		159
Commingled funds
Equity security commingled funds	0	[1]	0	[1]
Debt security commingled funds	0	[1]	0	[1]
Total investments	214		159
Currency swaps	0		0
Commodity contract derivatives	1		3
Commodity derivatives under FTP
Swap contracts	0		0
Total commodity derivatives under FTP	0		0
Total	215		162
Liabilities [Abstract]
Currency swaps	0		0
Interest rate swaps	0		0
Commodity contract derivatives	97		143
Commodity derivatives under FTP
Swap contracts	0		0
Total commodity derivatives under FTP	0		0
Total	$ 97		$ 143

[1] Commingled funds represent investment funds comprising multiple individual financial instruments and are classified in the table based on their existing investment portfolio as of the measurement date. Commingled funds primarily composed of one class of security are classified in that category.

[2] Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the counterparty or FCM. Deposits are made to TVA's margin cash accounts held with each FCM to offset any net liability positions in full for derivatives that are transacted with FCMs. TVA records currency swaps net of cash collateral received from or paid to the counterparty. See Note 15 — Offsetting of Derivative Assets and Liabilities.

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CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities
Net income (loss)	$ 469	$ 271	$ 60
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation and amortization (including amortization of debt issuance costs and premiums/discounts)	1,888	1,723	1,947
Amortization of nuclear fuel cost	279	268	264
Non-cash retirement benefit expense	572	622	607
Prepayment credits applied to revenue	(100)	(102)	(105)
Fuel cost adjustment deferral	(38)	97	(61)
Fuel cost tax equivalents	6	2	47
Environmental cleanup costs - Kingston ash spill - non cash	68	72	73
Changes in current assets and liabilities
Accounts receivable, net	(79)	114	89
Inventories and other current assets, net	34	27	(131)
Accounts payable and accrued liabilities	147	(296)	60
Accrued interest	2	1	(26)
Regulatory assets costs	(56)	(21)	(14)
Pension contributions	(256)	(6)	(8)
Environmental cleanup costs - Kingston ash spill, net	(109)	(99)	(108)
Insurance recoveries	175	47	5
Other, net	(22)	(123)	(125)
Net cash provided by operating activities	2,980	2,597	2,574
Cash flows from investing activities
Construction expenditures	(2,384)	(2,051)	(2,119)
Nuclear fuel expenditures	(326)	(287)	(361)
Purchases of investments, net	(48)	(48)	(48)
Loans and other receivables
Advances	(6)	(6)	(2)
Repayments	6	9	10
Other, net	2	(2)	7
Net cash used in investing activities	(2,756)	(2,385)	(2,513)
Cash flows from financing activities
Issues of power bonds	989	2,122	1,126
Issues of variable interest entities	0	360	1,000
Redemptions and repurchases of power bonds	(365)	(2,358)	(2,717)
Payments on debt of variable interest entities	(30)	(13)	(6)
Short-term debt issues (redemptions), net	(1,837)	924	1,024
Payments on leases and leasebacks	(73)	(446)	(84)
Proceeds from call monetization	0	0	60
Financing costs, net	(4)	(20)	(75)
Payments to U.S. Treasury	(14)	(27)	(27)
Other, net	8	(20)	(1)
Net cash (used in) provided by financing activities	(1,326)	522	300
Net change in cash and cash equivalents	(1,102)	734	361
Cash and cash equivalents at beginning of the year	1,602	868	507
Cash and cash equivalents at end of the year	$ 500	$ 1,602	$ 868

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Net Completed Plant

12 Months Ended

Sep. 30, 2014

Net Completed Plant [Abstract]

Net Completed Plant

Net Completed Plant

Net completed plant consisted of the following:

Net Completed Plant At September 30
	2014						2013
	Cost		Accumulated Depreciation		Net		Cost		Accumulated Depreciation		Net
Coal-fired	$	14,078	$	9,065	$	5,013	$	13,847	$	8,429	$	5,418
Gas and oil-fired	3,411		1,094		2,317		3,386		1,008		2,378
Nuclear	18,489		9,593		8,896		18,725		9,103		9,622
Transmission	6,519		2,683		3,836		6,300		2,562		3,738
Hydroelectric	2,547		889		1,658		2,392		892		1,500
Other electrical plant	1,550		885		665		1,452		792		660
Subtotal	46,594		24,209		22,385		46,102		22,786		23,316
Multipurpose dams	928		364		564		928		356		572
Other stewardship	42		16		26		43		15		28
Subtotal	970		380		590		971		371		600
Total	$	47,564	$	24,589	$	22,975	$	47,073	$	23,157	$	23,916

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Inventories, Net

12 Months Ended

Sep. 30, 2014

Inventory, Net [Abstract]

Inventories, Net

Inventories, Net

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

Inventories, Net At September 30
	2014			2013
Materials and supplies inventory	$	616		$	620
Fuel inventory	473			494
Emission allowance inventory	13			14
Allowance for inventory obsolescence	(46		)	(37		)
Inventories, net	$	1,056		$	1,091

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Proprietary Capital

12 Months Ended

Sep. 30, 2014

Stockholders' Equity Note [Abstract]

Proprietary Capital

Proprietary Capital

Appropriation Investment

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

The 1959 amendment to the TVA Act also required TVA, beginning in 1961, to make annual payments to the U.S. Treasury from net power proceeds as a repayment of and as a return on the Power Program Appropriation Investment until an additional $1.0 billion of the Power Program Appropriation Investment has been repaid.  TVA paid $10 million for 2014 and $20 million for 2013 as a repayment of the Power Program Appropriation Investment. 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 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.

Summary of Proprietary Capital Activity At or for the years ended September 30
	2014						2013
Appropriation Investment	Power Program			Nonpower  Programs			Power Program			Nonpower  Programs
Balance at beginning of year	$	268		$	4,351		$	288		$	4,351
Return of power program appropriation investment	(10		)	—			(20		)	—
Balance at end of year	258			4,351			268			4,351
Retained Earnings
Balance at beginning of year	4,767			(3,742		)	4,492			(3,731		)
Net income (expense) for year	477			(8		)	282			(11		)
Return on power program appropriation investment	(4		)	—			(7		)	—
Balance at end of year	5,240			(3,750		)	4,767			(3,742		)
Net proprietary capital at September 30	$	5,498		$	601		$	5,035		$	609

Payments to the U.S. Treasury

TVA paid the U.S. Treasury $4 million in 2014, $7 million in 2013, and $7 million in 2012 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 1.97 percent, 2.10 percent, and 2.33 percent for 2014, 2013, and 2012, respectively.

Accumulated Other Comprehensive Income (Loss)

The items included in Accumulated other comprehensive income (loss) consist of market valuation adjustments for certain derivative instruments.  See Note 15.

TVA records exchange rate gains and losses on debt in net income and marks its currency swap assets and liabilities to market through other comprehensive income.  TVA had unrealized gains of $4 million and $78 million in 2014 and 2013, respectively, on the mark-to-market of currency swaps. TVA then reclassifies an amount out of accumulated other comprehensive income into net income, offsetting the gain/loss from recording the exchange gain/loss on the debt.  The amounts reclassified from other comprehensive income into net income resulted in increases to net income of $2 million, $1 million, and $35 million in 2014, 2013, and 2012, respectively.  These reclassifications, coupled with the recording of the exchange gain/loss on the debt, did not have an impact on net income in 2014, 2013, and 2012.  Based on forecasted foreign currency exchange rates, TVA expects to reclassify approximately $37 million of losses from accumulated other comprehensive income to interest expense within the next twelve months to offset amounts anticipated to be recorded in interest expense related to exchange gain on the debt.

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Debt and Other Obligations

12 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

Debt and Other Obligations

.  Debt and Other Obligations

General

The TVA Act authorizes TVA to issue Bonds in an amount not to exceed $30.0 billion at any time.  At September 30, 2014, 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 United States, and the United States 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 out of 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; however, such treatment is not free from doubt. 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 minimum payments into the U.S. Treasury required by the TVA Act in repayment of, and as a return on, the Power Program Appropriation Investment, investment in power assets, additional reductions of TVA’s capital obligations, and other lawful purposes related to TVA’s power program.

The TVA Act and the Basic Resolution each contain two bond tests: the rate testand 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, 2014, TVA was in compliance with the rate test. See Note 1 — 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, 2010, and must next meet the bondholder protection test for the five-year period ending September 30, 2015.

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 was paid to TVA in accordance with the terms of the Southaven head lease. See Note 9 — Southaven. 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 9 — John Sevier. 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, 2014 and 2013 totaled approximately $1.3 billion.

Short-Term Debt

The weighted average rates applicable to short-term debt outstanding at September 30, 2014, 2013, and 2012, were nominal, 0.04 percent, and 0.09 percent, respectively.  During 2014, 2013, and 2012, the maximum outstanding balances of TVA short-term borrowings held by the public were $2.4 billion, $3.4 billion, and $3.2 billion, respectively.  For these same years, the average amounts (and weighted average interest rates) of TVA short-term borrowings were approximately $1.7 billion (0.05 percent), $1.9 billion (0.08 percent), and $1.1 billion (0.08 percent), respectively.

Put and Call Options

Bond issues of $515 million held by the public are redeemable in whole or in part, at TVA’s option, on call dates ranging from the present to 2020 and at call prices of 100 percent of the principal amount.  Fifteen Bond issues totaling $375 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 are classified as long-term as of September 30, 2014 and 2013.

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

The coupon rate for the 1998 Series D PARRS, which mature in June 2028, has been reset six times, from an initial rate of 6.75 percent to the current rate of 3.830 percent.  In connection with these resets, $251 million of the Bonds have been redeemed, so that $324 million of the Bonds were outstanding at September 30, 2014.  The coupon rate for the 1999 Series A PARRS, which mature in May 2029, has been reset five times, from an initial rate of 6.50 percent to the current rate of 3.955 percent.  In connection with these resets, $255 million of the Bonds have been redeemed, so that $270 million of the Bonds were outstanding at September 30, 2014.

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, which occur in the third quarter of TVA's fiscal year.  If the 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.  At September 30, 2014, TVA has not determined that it is probable that the reset rate will be less than than the current coupon rate on the PARRS on the calculation dates; therefore, the par amount outstanding for each series of PARRS was classified as long-term debt.

Debt Securities Activity

The table below summarizes the long-term debt securities activity for the period from October 1, 2012, to September 30, 2014.

Debt Securities Activity For the years ended September 30
	2014			2013
Issues
Variable interest entities	$	—		$	360
electronotes®	—			152
2012 Series B(1)	—			1,000
2013 Series A(2)	—			1,000
2014 Series A(3)	1,000			—
Discount on debt issues	(11		)	(30		)
Total	$	989		$	2,482
Redemptions/Maturities(4)
Variable interest entities	$	30		$	13
electronotes®	335			50
1998 Series C	—			1,359
1998 Series D	—			2
1999 Series A	—			1
2003 Series C	—			940
2009 Series A	4			4
2009 Series B	26			2
Total	$	395		$	2,371

Notes

(1) The 2012 Series B bonds were issued at 97.49 percent of par.

(2) The 2013 Series A bonds were issued at 99.52 percent of par.

(3) The 2014 Series A bonds were issued at 98.94 percent of par.

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

Debt Outstanding

Total debt outstanding at September 30, 2014, and 2013, consisted of the following:

Short-Term Debt At September 30
CUSIP or Other Identifier	Maturity	Call/(Put) Date	Coupon Rate	2014		2013
Short-term debt, net of discounts				$	596	$	2,432
Current maturities of long-term debt of variable interest entities issued at par				32		30
Current maturities of power bonds issued at par
880591EE8	11/15/2014		2.250%	3		3
880591EF5	12/15/2014		3.770%	26		26
880591DY5	6/15/2015		4.375%	1,000		—
88059TEL1	11/15/2014		2.650%	3		3
Total current maturities of power bonds issued at par				1,032		32
Total current debt outstanding, net				$	1,660	$	2,494

Long-Term Debt(1) At September 30
CUSIP or Other Identifier	Maturity	Coupon Rate			Call Date	2014 Par		2013 Par		Stock Exchange Listings
electronotes®(2)	05/15/2020 - 02/15/2043	2.375 - 4.375%			2/15/2015 - 02/15/2018	$	387	$	723	None
880591DY5	6/15/2015	4.375%				—		1,000		New York, Luxembourg
880591EE8(3)	11/15/2015	2.250%				2		4		None
880591DS8	12/15/2016	4.875%				524		524		New York
880591EA6	7/18/2017	5.500%				1,000		1,000		New York, Luxembourg
880591CU4	12/15/2017	6.250%				650		650		New York
880591EC2	4/1/2018	4.500%				1,000		1,000		New York, Luxembourg
880591EQ1	10/15/2018	1.750%				1,000		1,000		New York
880591EL2	2/15/2021	3.875%				1,500		1,500		New York
880591DC3	6/7/2021	5.805%	(4	)		324		324		New York, Luxembourg
880591EN8	8/15/2022	1.875%				1,000		1,000		New York
880591ER9	9/15/2024	2.875%				1,000		—		New York
880591CJ9	11/1/2025	6.750%				1,350		1,350		New York, Hong Kong, Luxembourg, Singapore
880591300(5)	6/1/2028	3.830%				324		324		New York
880591409(5)	5/1/2029	3.955%				270		270		New York
880591DM1	5/1/2030	7.125%				1,000		1,000		New York, Luxembourg

880591DP4	6/7/2032	6.587%	(4	)		406			405			New York, Luxembourg
880591DV1	7/15/2033	4.700%				472			472			New York, Luxembourg
880591EF5(3)	6/15/2034	3.770%				388			414			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%	(4	)		243			243			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
Subtotal						22,037			22,400
Unamortized discounts, premiums, and other						(89		)	(85		)
Total long-term outstanding power bonds, net						21,948			22,315
Long-term debt of variable interest entities						1,279			1,311
Total long-term debt, net						$	23,227		$	23,626

Notes

(1)  Includes net exchange losses from currency transactions of $44 million at September 30, 2014 and $43 million at September 30, 2013.

(2)  Includes one electronotes^® issue with partial maturities of principal for each required annual payment.

(3)  These Bonds include partial maturities of principal for each required annual payment.

(4)  The coupon rate represents TVA’s effective interest rate.

(5)  TVA PARRS, CUSIP numbers 880591300 and 880591409, may be redeemed under certain conditions.  See Put and Call Options.

Maturities Due in the Year Ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Long-term power bonds and long-term debt of variable interest entities including current maturities(1)	$	1,064	$	65	$	1,590	$	1,718	$	1,070	$	18,829	$	24,336
Short-term debt, net of discounts	596		—		—		—		—		—		596

Note

(1) Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 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 fiscal year 2015 with a maturity date of September 30, 2015. 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 plans to use the credit facility as 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 United States with maturities from date of issue of one year or less. There were no outstanding borrowings under the facility at September 30, 2014. The availability of this credit facility may be impacted by how the U.S. government addresses the situation of approaching its debt limit.

TVA also has funding available in the form of three long-term revolving credit facilities totaling $2.5 billion. One $1.0 billion credit facility matures on June 25, 2017, another $1.0 billion credit facility matures on December 13, 2017, and the $500 million credit facility matures on April 5, 2018. 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 $2.5 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, 2014, and September 30, 2013, there were $1.0 billion and $0.8 billion, respectively, of letters of credit outstanding under the facilities, and there were no borrowings outstanding. See Note 15 — Other Derivative Instruments — Collateral.

Lease/Leasebacks

Prior to 2004, TVA received approximately $945 million in proceeds by entering into leaseback transactions for 24 new peaking combustion turbine units ("CTs"). TVA also received approximately $389 million in proceeds by entering into a leaseback transaction for qualified technological equipment and software ("QTE") in 2003. Due to TVA's continuing involvement in the operation and maintenance of the leased units and equipment and its control over the distribution of power produced by the combustion turbine facilities during the leaseback term, TVA accounted for the lease proceeds as financing obligations. At September 30, 2014, and September 30, 2013, the outstanding leaseback obligations related to CTs and QTE were $691 million and $761 million, respectively.

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Derivatives Under Financial Trading Program (Details) (USD $)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013
Derivative
FTP transaction limit	$ 130,000,000
Unrealized gains/losses on derivatives	0		0
Natural Gas Futures
Derivative
Notional amount	0		0
Fair value	0		0
Fuel Oil/Crude Oil Futures
Derivative
Notional amount	0		0
Fair value	0		0
Natural Gas Swap
Derivative
Notional amount	102,227,500	[1]	152,922,500	[1]
Fair value	(103,000,000)	[1]	(169,000,000)	[1]
Fuel Oil/Crude Oil Swap
Derivative
Notional amount	0		1,205,000	[1]
Fair value	0		3,000,000	[1]
Natural Gas Option
Derivative
Notional amount	0		0
Fair value	0		0
Fuel Oil/Crude Oil Option
Derivative
Notional amount	0		0
Fair value	0		0
Natural Gas Total Contracts
Derivative
Notional amount	102,227,500	[1]	152,922,500	[1]
Unrealized gains/losses on derivatives	(103,000,000)		(169,000,000)
Decrease (increase) in fuel expense	(34,000,000)		(78,000,000)
Decrease (increase) in purchased power expense	(11,000,000)		(51,000,000)
Fair value	(103,000,000)	[1]	(169,000,000)	[1]
Fuel Oil/Crude Oil Total Contracts
Derivative
Notional amount	0		1,205,000	[1]
Unrealized gains/losses on derivatives	0		3,000,000
Decrease (increase) in fuel expense	2,000,000		4,000,000
Fair value	0		3,000,000	[1]
Coal Contract Total Contracts
Derivative
Unrealized gains/losses on derivatives	0		0
Decrease (increase) in fuel expense	0		(1,000,000)
Fair value	0		0
Closed Derivative Contracts
Derivative
Fair value	$ (5,000,000)		$ (8,000,000)
Swap contracts
Derivative
Remaining terms	3 years

[1] Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the broker or other counterparty. Notional amounts disclosed represent the net absolute value of contractual amounts.

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Variable Interest Entities

12 Months Ended

Sep. 30, 2014

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Variable Interest Entities

Variable Interest Entities

A VIE is an entity that either (1) has insufficient equity to permit the entity to finance its activities without additional subordinated financial support or (2) has equity investors who lack the characteristics of owning a controlling financial interest. The analysis to determine whether an entity is a VIE considers factors such as contracts with an entity, credit support for an entity, the adequacy of the equity investment of an entity, the extent of an entity's activities that either involve or are conducted on behalf of an investor with disproportionate voting rights, and the relationship of voting power to the amount of equity invested in an entity. A VIE is consolidated by its primary beneficiary. The primary beneficiary has both (i) the power to direct the activities that most significantly impact the entity's economic performance and (ii) the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. The determination of the primary beneficiary requires continual reassessment.

When TVA determines that it has a variable interest in a variable interest entity, 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.

Southaven

On August 9, 2013, TVA entered into a 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 Seven States Southaven, LLC ("SSSL"). SHLLC is a special single-purpose entity, also formed in June 2013, established to acquire and hold the membership interests of 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 scheduled amortizing, semi-annual payments due each August 15 and February 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. The sale of the SCCG notes, the membership interests in SCCG, and the SHLLC notes all closed on August 9, 2013. 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 scheduled pre-determined payments to be made to Seven States Southaven, LLC on each lease payment date by SHLLC as agreed in SHLLC’s formation documents (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.

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.

John Sevier

On January 17, 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 millionsecured 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 is allocated. 

The membership interests held by Holdco in JSCCG were purchased with proceeds from the issuance of $100 millionof secured notes (the “Holdco notes") and are subject to mandatory redemption pursuant to scheduled amortizing, semi-annual payments due each January 15 and July 15, with a final payment due on January 15, 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 on January 17, 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.

The financial statement items attributable to carrying amounts and classifications of JSCCG, Holdco, and SCCG as of September 30, 2014 and 2013, as reflected in the Consolidated Balance Sheets, are as follows:

Summary of Impact of VIEs on Consolidated Balance Sheets At September 30
	2014		2013
Current liabilities of VIE
Accrued interest of VIE	$	12	$	12
Current portion of membership interests of VIE subject to mandatory redemption	2		2
Current maturities of long-term debt of VIE	32		30
Total current liabilities of VIE	46		44
Other liabilities of VIE
Membership interests of VIE subject to mandatory redemption	37		38
Long-term debt of VIE, net
Long-term debt of VIE	1,279		1,311
Total liabilities of VIE	$	1,362	$	1,393

Interest expense of $64 million, $50 million and $34 million related to debt of variable interest entities 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, 2014, 2013, and 2012, respectively.

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

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Accounts Receivable, Net Accounts Receivable, Net (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Accounts Receivable, Net
Power receivables	$ 1,576	$ 1,495
Other receivables	101	73
Allowance for uncollectible accounts	(1)	(1)	(7)	(1)
Accounts receivable, net	$ 1,676	$ 1,567

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Benefit Plans Estimated Future Benefit Payments (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014
Pension Benefits
Defined Benefit Plan Disclosure
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	$ 712
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	715
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	720
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	724
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	731
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	3,759
Other Post-retirement Benefits
Defined Benefit Plan Disclosure
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	39
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	40
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	41
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	41
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	41
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 186

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Other Long-Term Assets

12 Months Ended

Sep. 30, 2014

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

Other Long-Term Assets

Other Long-Term Assets

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

Other Long-Term Assets At September 30
	2014		2013
EnergyRight® receivables	$	123	$	117
Unamortized debt issue cost of power bonds	68		75
Loans and other long-term receivables, net	87		73
Coal contract derivative assets	—		1
Prepaid capacity payments	58		62
Currency swap assets, net	—		28
Restricted cash	64		—
Other	83		89
Total other long-term assets	$	483	$	445

In association with the EnergyRight^® Solutions program, LPCs offer financing to end-use customers for the purchase of energy-efficient equipment. 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 loan 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. As of September 30, 2014 and September 30, 2013, the carrying amount of the loans receivable, net of discount, reported in Accounts receivable, net was approximately $33 million. See Note 11 for information regarding the associated financing obligation.

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Regulatory Assets and Liabilities

12 Months Ended

Sep. 30, 2014

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities

Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates.  Regulatory liabilities generally represent obligations to make refunds to customers for previous collections for costs that are not likely to be incurred or deferral of gains that will be credited to customers in future periods.  Components of regulatory assets and regulatory liabilities are summarized in the table below. 

Regulatory Assets and Liabilities At September 30
	2014		2013
Current regulatory assets
Unrealized losses on commodity derivatives	$	134	$	183
Deferred nuclear generating units	237		237
Environmental agreements	54		73
Fuel cost adjustment receivable	9		—
Environmental cleanup costs – Kingston ash spill	47		68
Total current regulatory assets	481		561
Non-current regulatory assets
Deferred pension costs and other post-retirement benefits costs	4,297		4,076
Unrealized losses on interest rate derivatives	957		808
Nuclear decommissioning costs	931		893
Environmental cleanup costs - Kingston ash spill	421		681
Non-nuclear decommissioning costs	645		571
Deferred nuclear generating units	1,255		1,438
Unrealized losses on commodity derivatives	72		139
Environmental agreements	108		189
Other non-current regulatory assets	308		336
Total non-current regulatory assets	8,994		9,131
Total regulatory assets	$	9,475	$	9,692
Current regulatory liabilities
Fuel cost adjustment tax equivalents	$	182	$	176
Fuel cost adjustment liability	—		29
Unrealized gains on commodity derivatives	2		7
Total current regulatory liabilities	184		212
Non-current regulatory liabilities
Unrealized gains on commodity derivatives	—		1
Total non-current regulatory liabilities	—		1
Total regulatory liabilities	$	184	$	213

Unrealized Gains (Losses) on Commodity Derivatives.  Unrealized gains (losses) on coal purchase contracts, included as part of unrealized losses on commodity derivatives, relate to the mark-to-market ("MtM") valuation of coal purchase contracts that contain options to purchase additional or lesser quantities.  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 2018.  Unrealized gains and losses on contracts with a maturity of less than one year are included as a current regulatory asset or liability on TVA's consolidated balance sheets.  See Note 15.

Deferred gains and losses relating to TVA’s Financial Trading Program ("FTP") represent net unrealized gains and losses on swaps, futures, options, and combinations of these instruments and are also included as part of unrealized losses on commodity derivatives.  The program is used to reduce TVA’s economic risk exposure associated with purchases and sales of commodities used in electricity generation, purchases, and sales.  TVA defers all FTP MtM unrealized gains or losses as regulatory liabilities or assets, respectively, and records realized gains or losses in fuel and purchased power expense to match the delivery period of the underlying commodity product.  Net unrealized losses at September 30, 2014, and September 30, 2013, were approximately $103 million and $166 million, respectively.  This accounting treatment reflects TVA’s ability and intent to recover the cost of these commodity contracts in future periods through the fuel cost adjustment.  The current regulatory asset/liability for net unrealized gains and losses, included as part of the commodity derivatives, represents deferred gains and losses from contracts with a maturity of less than one year.

Deferred Nuclear Generating Units and Construction Costs.  In July 2005, the TVA Board approved the amortization, and inclusion into rates, of TVA’s $3.9 billion investment in the two deferred nuclear generating units at Bellefonte over a 10-year recovery period beginning in 2006.  In August 2011, the TVA Board approved the completion of Bellefonte Unit 1. Approximately $619 million of the remaining balance in the deferred nuclear generating units regulatory asset at that date did not continue to be amortized into rates, but was to be included in the Bellefonte plant asset balance at completion. This amount had been segregated into a separate non-current regulatory asset account titled Construction costs. TVA is evaluating the completion of Bellefonte Unit 1. In the interim, work at the site has been slowed to better allocate resources on nearer-term priorities as both budget and staffing levels for the project have been reduced in the 2014 budget. TVA believes that the resulting budgeting and staffing levels should be sufficient to preserve Bellefonte for potential future development. TVA plans to utilize its integrated resource planning process to help determine how Bellefonte best supports TVA's overall efforts to continue to meet customer demand with low-cost, reliable power. In November 2013, in accordance with the regulated operations property, plant and equipment accounting guidance, the TVA Board approved the treatment of all amounts currently included in Construction in progress related to Bellefonte as a regulatory asset. Additionally, the TVA Board approved combining (1) the amounts related to Bellefonte previously included in Construction in progress, (2) the $619 million in Regulatory asset-Construction costs, and (3) the remaining amounts included in Regulatory asset-Deferred nuclear generating units into a single regulatory asset titled Deferred nuclear generating units totaling $1.5 billion at September 30, 2014. Such amounts have been classified as a Regulatory asset in the September 30, 2014 Consolidated Balance Sheet. The TVA Board approved the recovery of this asset in future rates at an amount of $237 million per year until fully recovered. The amount to be amortized over the next year is included as a current regulatory asset on TVA's consolidated balance sheets.

Environmental Agreements.  In conjunction with the Environmental Agreements (see Note 21 — Legal Proceedings — 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 2014, $138 million has been paid with respect to energy efficiency projects, $50 million has been paid to Alabama, Kentucky, North Carolina, and Tennessee, and $10 million has been paid with respect to civil penalties. The remaining amounts will be charged to expense and recovered in rates over future periods as payments are made.

Environmental Cleanup Costs – Kingston Ash Spill.  In August 2009, TVA began using 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 October 1, 2009. At September 30, 2009, TVA’s remediation cost estimate of $933 million was deferred as a regulatory asset. During 2010, the estimate was revised and increased by $192 million to a total estimate of $1.1 billion. The additional amount will be amortized over the remaining term. As of September 30, 2014, TVA had received insurance proceeds of $267 million, related to insurance claim settlements. The insurance proceeds are being recorded as reductions to the regulatory asset and will reduce 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. See Note 10.

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 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 are recovered or refunded in fuel rates.

Deferred Pension Costsand Other Post-retirement Benefit Costs.  TVA measures its benefit obligations related to pension and other post-retirement benefit ("OPEB") costs at each year-end balance sheet date.  TVA recognizes the funded status of the plans on TVA's consolidated balance sheets which in an unregulated environment would result in a corresponding offset to 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 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 in allowable costs for ratemaking purposes.

TVA has classified all amounts related to unrecognized prior service costs, net actuarial gains or losses, and the funded status as regulatory assets as such amounts are probable of collection in future rates. In 2015, TVA will begin including its cash contributions to the pension plan in the rate-making formula; accordingly, beginning October 1, 2014, TVA will recognize pension costs as regulatory assets to the extent that the amount calculated under GAAP as pension expense differs from the amount TVA contributes to the pension plan.

These regulatory assets are classified as long-term, which is consistent with the pension and post-retirement liabilities, and 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, as calculated by the actuaries. Ultimately this regulatory asset will be recognized in the consolidated statements of operations in the form of pension expense as the actuarial liability is eliminated in future periods. These costs are included in other non-current regulatory assets. See Note 20 — Obligations and Funded Status.

Unrealized Losses on Interest Rate Derivatives.  TVA uses regulatory accounting treatment to defer the MtM unrealized gains and losses on certain interest rate derivative contracts to reflect that the gain or loss is included in the ratemaking formula when these contracts actually settle.  The unrealized losses on these interest rate derivatives are recorded on TVA’s consolidated balance sheets as non-current regulatory assets and the related realized gains or losses, if any, are recorded in TVA’s consolidated statements of operations.

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 Nuclear Decommissioning Trust ("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— 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.

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 Asset Retirement Trust ("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 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.  There is not a specified recovery period; therefore, the regulatory asset is classified as long-term, consistent with the ART investments and ARO liability.

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

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.

Nuclear Training Costs.  As a result of refurbishing and restarting Browns Ferry Unit 1 in 2007 and the construction and startup of Watts Bar Nuclear Plant ("Watts Bar") Unit 2, nuclear training costs associated with these units have been deferred as a regulatory asset and will be amortized over a cost recovery period equivalent to the expected useful life of the operating nuclear units.

Retirement Removal Costs.  Retirement removal costs that are not legally required are capitalized into fixed assets to be depreciated consistent with the lives in the depreciation study. See Note 1 — Property, Plant, and Equipment, andDepreciation — Depreciation. The TVA Board has consistently set rates to cover the depreciation of these assets; therefore, these assets are probable of future recovery.

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, the percent of the calculation that relates to a future asset or liability for tax equivalent payments is recorded as a current regulatory asset or liability and paid in the following year.

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Kingston Fossil Plant Ash Spill

12 Months Ended

Sep. 30, 2014

Environmental Remediation Obligations [Abstract]

Kingston Fossil Plant Ash Spill

Kingston Fossil Plant Ash Spill

The Event

In December 2008, one of the dredge cells at Kingston failed, and approximately five million cubic yards of water and coal fly ash flowed out of the cell. TVA is continuing cleanup and recovery efforts in conjunction with federal and state agencies.  TVA completed the removal of time-critical ash from the river during the third quarter of 2010, and removal of the remaining ash is considered to be non-time-critical.  In November 2012, the EPA and the Tennessee Department of Environment and Conservation ("TDEC") approved a plan to allow the Emory River's natural processes to remediate the remaining ash in the river, and to conduct a long-term monitoring program. TVA estimates that the physical cleanup work will be completed in the spring of 2015.  A final assessment, issuance of a completion report, and approval by the State of Tennessee and the EPA are expected to occur by the third quarter of 2015.  

Claims and Litigation

See Note 21 — Legal Proceedings — Legal Proceedings Related to the Kingston Ash Spill and — Civil Penalty and Natural Resource Damages for the Kingston Ash Spill.

Financial Impact

TVA recorded an estimate of $1.1 billion for the cost of cleanup related to this event.  In August 2009, TVA began using regulatory accounting treatment to defer all actual costs already incurred and expected future costs related to the ash spill.  The cost is being charged to expense as it is collected in rates over 15 years, beginning October 1, 2009.  

Amounts spent since the event through September 30, 2014, totaled $1.1 billion.  The remaining estimated liability at September 30, 2014, was $21 million and is included in Current liabilities.

TVA has not included the following categories of costs in the above estimate since it has been determined that these costs are currently either not probable or not reasonably estimable: penalties (other than the penalties set out in a June 2010 TDEC order), regulatory directives, natural resources damages (other than payments required under a memorandum of agreement with TDEC and the U.S. Fish and Wildlife Service establishing a process and a method for resolving the natural resource damages claim), future lawsuits, future claims, long-term environmental impact costs, final long-term disposition of the ash processing area, and costs associated with new laws and regulations.  There are certain other costs that will be incurred that have not been included in the estimate as they are appropriately accounted for in other areas of the consolidated financial statements.  Associated capital asset purchases are recorded in property, plant, and equipment.  Ash handling and disposition costs from current plant operations are recorded in operating expenses.  A portion of the dredge cell closure costs are also excluded from the estimate, as they are included in the non-nuclear ARO liability.

Insurance

TVA had property and excess liability insurance programs in place at the time of the Kingston ash spill.  TVA pursued claims under both the property and excess liability programs and has settled all of its property insurance claims and some of its excess liability insurance claims.  In April 2012, TVA initiated arbitration proceedings against the remaining excess liability insurance companies in accordance with the policies’ dispute resolution provisions. TVA is seeking recovery of certain costs incurred in the cleanup project, including the costs of removing ash from property or waters owned by the State of Tennessee, and related expenses. TVA has received insurance proceeds of $267 million, of which $175 million were received during the year ended September 30, 2014. The insurance proceeds are being recorded as reductions to the regulatory asset and will reduce costs collected in future rates.

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Regulatory Assets and Liabilities Regulatory Assets and Liabilities - Table (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Regulatory Assets and Liabilities
Current regulatory assets	$ 481	$ 561
Non-current regulatory assets	8,994	9,131
Regulatory assets	9,475	9,692
Current regulatory liabilities	184	212
Non-current regulatory liabilities	0	1
Regulatory liabilities	184	213
Fuel cost adjustment tax equivalents
Regulatory Assets and Liabilities
Current regulatory liabilities	182	176
Fuel cost adjustment receivable/payable
Regulatory Assets and Liabilities
Current regulatory liabilities	0	29
Unrealized gains/losses on commodity derivatives
Regulatory Assets and Liabilities
Current regulatory liabilities	2	7
Non-current regulatory liabilities	0	1
Unrealized gains/losses on commodity derivatives
Regulatory Assets and Liabilities
Current regulatory assets	134	183
Non-current regulatory assets	72	139
Deferred nuclear generating units
Regulatory Assets and Liabilities
Current regulatory assets	237	237
Non-current regulatory assets	1,255	1,438
Regulatory assets	1,500
Environmental agreements
Regulatory Assets and Liabilities
Current regulatory assets	54	73
Non-current regulatory assets	108	189
Fuel cost adjustment receivable/payable
Regulatory Assets and Liabilities
Current regulatory assets	9	0
Environmental cleanup costs - Kingston ash spill
Regulatory Assets and Liabilities
Current regulatory assets	47	68
Non-current regulatory assets	421	681
Deferred pension costs and other post-retirement benefits costs
Regulatory Assets and Liabilities
Non-current regulatory assets	4,297	4,076
Unrealized losses on interest rate derivatives
Regulatory Assets and Liabilities
Non-current regulatory assets	957	808
Nuclear decommissioning costs
Regulatory Assets and Liabilities
Non-current regulatory assets	931	893
Non-nuclear decommissioning costs
Regulatory Assets and Liabilities
Non-current regulatory assets	645	571
Other non-current regulatory assets
Regulatory Assets and Liabilities
Non-current regulatory assets	$ 308	$ 336

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Related Parties Related Parties (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Related Parties
Amount of appropriations currently received	$ 0
Amount of appropriation investment that must be repaid	1,000,000,000
Current borrowing capacity	150,000,000
Sales of electricity	128,000,000	120,000,000	117,000,000
Other income	137,000,000	102,000,000	164,000,000
Operating and maintenance	286,000,000	314,000,000	375,000,000
Cash and cash equivalents	35,000,000	38,000,000	32,000,000
Accounts receivable, net	85,000,000	58,000,000	49,000,000
Accounts payable and accrued liabilities	146,000,000	133,000,000	204,000,000
Long-term power bonds, net	3,000,000	0	0
Return on power program appropriation investment	4,000,000	7,000,000	7,000,000
Return of power program appropriation investment	$ 10,000,000	$ 20,000,000	$ 20,000,000

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Collateral (Details) (USD $)			12 Months Ended
	Sep. 30, 2014 Credit of Customers Customers	Sep. 30, 2013 Credit of Customers Customers	Sep. 30, 2014 Collateral
Derivative
Number of customers that represent the percent of outstanding accounts receivable	3	3
Aggregate fair value of derivative instruments with credit-risk related contingent features that were in a liability position			$ 1,400,000,000
Collateral obligations			900,000,000
Collateral already posted			1,000,000,000
Likely cash collateral obligation increase if credit is downgraded			$ 22,000,000

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Variable Interest Entities Variable Interest Entities (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Aug. 09, 2013	Jan. 17, 2012
VIE Financing
Membership interests of VIE subject to mandatory redemption	$ 50	$ 50		$ 40
Total liabilities	1,362	1,393			1,000
Interest expense	64	50	34
SCCG
VIE Financing
Face Amount				360
JSCCG
VIE Financing
Face Amount					900
Holdco
VIE Financing
Face Amount					100
Accrued interest of VIE
VIE Financing
Total liabilities	12	12
Current portion of membership interests of VIE subject to mandatory redemption
VIE Financing
Total liabilities	2	2
Current maturities of long-term debt of VIE
VIE Financing
Total liabilities	32	30
Total current liabilities of VIE
VIE Financing
Total liabilities	46	44
Membership interests of VIE subject to mandatory redemption
VIE Financing
Total liabilities	37	38
Long-term debt of VIE
VIE Financing
Total liabilities	$ 1,279	$ 1,311

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Benefit Plans Components of Net Periodic Benefit Cost (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Pension Benefits
Defined Benefit Plan Disclosure
Service cost	$ 130	$ 154	$ 139
Interest cost	558	468	490
Expected return on plan assets	(435)	(428)	(437)
Amortization of prior service credit	(21)	(22)	(23)
Recognized net actuarial loss	285	377	361
Total net periodic benefit cost	517	549	530
Other Post-retirement Benefits
Defined Benefit Plan Disclosure
Service cost	18	24	19
Interest cost	32	31	35
Expected return on plan assets	0	0	0
Amortization of prior service credit	(6)	(6)	(6)
Recognized net actuarial loss	11	25	29
Total net periodic benefit cost	$ 55	$ 74	$ 77

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Other Long-Term Assets Other Long-Term Assets (Details) (USD $) In Millions, unless otherwise specified			12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014 Energy Right Program	Sep. 30, 2014 Other Noncurrent Assets [Member]	Sep. 30, 2013 Other Noncurrent Assets [Member]	Sep. 30, 2014 Accounts Receivable [Member]	Sep. 30, 2013 Accounts Receivable [Member]
Other Long-Term Assets
EnergyRight receivables	$ 166	$ 150		$ 123	$ 117	$ 33	$ 33
Unamortized debt Issue cost of power bonds				68	75
Loans and other long-term receivables, net	92	73		87	73
Coal contract derivative assets				0	1
Prepaid capacity payments				58	62
Currency swap assets, net	0	28		0	28
Restricted cash				64	0
Other				83	89
Total other long-term assets	$ 483	$ 445
Number of days in default			180 days

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Fair Value Measurements Fair Value Measurements - Estimated Values of Financial Instruments Not Recorded at Fair Value (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Aug. 09, 2013
Estimated Values of Financial Intruments Not Recorded at Fair Value
EnergyRight receivables (including current portion)	$ 166	$ 150
Loans and other long-term receivables, net (including current portion)	81	67
EnergyRight purchase obligation (including current portion)	215	222
Unfunded Loan Commitments	18	13
Membership interests of VIE subject to mandatory redemption (including current portion)	50	50	40
Long-term outstanding power bonds (including current maturities), net	26,889	24,603
Long-term debt of variable interest entities (including current maturities)	1,425	1,386
Portion at Other than Fair Value Measurement [Member]
Estimated Values of Financial Intruments Not Recorded at Fair Value
EnergyRight receivables (including current portion)	156	150
Loans and other long-term receivables, net (including current portion)	92	73
EnergyRight purchase obligation (including current portion)	190	186
Unfunded Loan Commitments	0	0
Membership interests of VIE subject to mandatory redemption (including current portion)	39	40
Long-term outstanding power bonds (including current maturities), net	22,980	22,347
Long-term debt of variable interest entities (including current maturities)	$ 1,300	$ 1,300

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Benefit Plans Benefit Plans (Policies)

12 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

Benefit Plans

Accounting Mechanisms

Regulatory Accounting.  TVA has classified all amounts related to unrecognized prior service costs, net actuarial gains or losses, and the funded status as regulatory assets as such amounts are probable of collection in future rates. In 2015, TVA began including its cash contributions to the pension plan in the rate-making formula; accordingly, on October 1, 2014, TVA began recognizing pension costs as regulatory assets to the extent that the amount calculated under GAAP as pension expense differs from the amount TVA contributes to the pension plan.

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 active employees.

Asset Method.  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.  Since the “market-related” value of assets recognizes investment gains and losses over a three-year period, the future value of assets will be impacted as previously deferred gains or losses are recognized.  The “market-related” value is used in calculating expected return on plan assets and net gain or loss for pension cost determination.

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Commitments and Contingencies Commitments and Contingencies (Tables)

12 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

At September 30, 2014, the amounts of contractual cash commitments maturing in each of the next five years and beyond are shown below:

Commitments and Contingencies Payments due in the years ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Debt(1)	$	1,628	$	32	$	1,555	$	1,682	$	1,032	$	17,692	$	23,621
Debt of VIEs	32		33		35		36		38		1,137		1,311
Membership interests of variable interest entity subject to mandatory redemption	2		2		2		2		2		29		39
Lease obligations
Capital	13		13		13		13		12		167		231
Non-cancelable operating	38		36		34		27		25		63		223
Purchase obligations
Power	220		222		232		235		239		3,364		4,512
Fuel	1,335		862		477		552		492		1,579		5,297
Other	304		215		202		199		192		1,640		2,752
Unfunded loan commitments	13		—		—		—		—		—		13
Payments on other financings	104		104		104		104		96		305		817
Total	$	3,689	$	1,519	$	2,654	$	2,850	$	2,128	$	25,976	$	38,816

Note

(1) Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million.

Energy Prepayment Obligations

Energy Prepayment Obligations Payments due in the years ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Energy Prepayment Obligations	$	100	$	100	$	100	$	100	$	10	$	—	$	410

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Risk Management Activities and Derivative Transactions

12 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Risk Management Activities and Derivative Transactions

Risk Management Activities and Derivative Transactions

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 risks.  To help manage certain of these risks, TVA has entered into various derivative transactions: commodity option contracts, forward contracts, swaps, swaptions, futures, and options on futures.  Other than certain derivative instruments in investment funds, it is TVA's policy to enter into these derivative transactions solely for hedging purposes and not for speculative purposes.

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 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	2014		2013
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	$	4	$	78

Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2) Amount of Gain (Loss) Reclassified from OCI to Interest Expense For the years ended September 30
Derivatives in Cash Flow Hedging Relationship	2014		2013
Currency swaps	$	2	$	1

Note

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 $37 million of losses from AOCI to interest expense within the next twelve months to offset amounts anticipated to be recorded in interest expense related to exchange gain on the debt.

Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment Amount of Gain (Loss) Recognized in Income on Derivatives(1) For the years ended September 30
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2014			2013
Interest rate swaps	To fix short-term debt variable rate to a fixed rate (interest rate risk)	MtM gains and losses are recorded as regulatory assets or liabilities until settlement, at which time the gains/losses are recognized in gain/loss on derivative contracts.(2)	$	—		$	—
Commodity contract derivatives	To protect against fluctuations in market prices of purchased coal or natural gas  (price risk)	MtM gains and losses are recorded as regulatory assets or liabilities. Realized gains and losses due to contract settlements are recognized in fuel expense as incurred.	(64		)	(11		)
Commodity derivatives under FTP	To protect against fluctuations in market prices of purchased commodities (price risk)	MtM 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.	(43		)	(126		)

Notes

(1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income but instead are deferred as regulatory assets and liabilities. As such, there was no related gain (loss) recognized in income for these unrealized gains (losses) for the years ended 2014 and 2013.

(2) Generally, TVA maintains a level of outstanding discount notes equal to or greater than the notional amount of the interest rate swaps. However, in September 2014 TVA issued long-term Bonds in anticipation of the maturity of other long-term debt, and used the proceeds to pay down discount notes, which caused the balance of discount notes outstanding at September 30, 2014, to fall below the notional amount of the interest rate swaps. There is no impact on the statements of operations due to the use of regulatory accounting for these items.

Mark-to-Market Values of TVA Derivatives At September 30
	2014				2013
Derivatives that Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Currency swaps
£200 million Sterling	$	(15	)	Other long-term liabilities	$	(15	)	Other long-term liabilities
£250 million Sterling	56			Other long-term assets	51			Other long-term assets
£150 million Sterling	8			Other long-term assets	10			Other long-term assets
Derivatives that Do Not Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Interest rate swaps
$1.0 billion notional	(987		)	Other long-term liabilities	(886		)	Other long-term liabilities
$476 million notional	(349		)	Other long-term liabilities	(300		)	Other long-term liabilities
$42 million notional	(12		)	Other long-term liabilities	(13		)	Other long-term liabilities
Commodity contract derivatives	(96		)	Other current assets $1; Other long-term liabilities $(17); Accounts payable and accrued liabilities $(80)	(141		)	Other long-term assets $1; Other current assets $2; Other long-term liabilities $(35); Accounts payable and accrued liabilities $(109)
FTP
Derivatives under FTP(1)	(103		)	Other current assets $(69); Other long-term liabilities $(14); Accounts payable and accrued liabilities $(20)	(166		)	Other current assets $(97); Other long-term liabilities $(36); Accounts payable and accrued liabilities $(33)

Note

(1)   Fair values of certain derivatives under the FTP that were in net liability positions totaling $69 million and $100 million at September 30, 2014 and September 30, 2013, respectively, are recorded in TVA's margin cash accounts in Other current assets. These derivatives are transacted with futures commission merchants, and cash deposits have been posted to the margin cash accounts held with each futures commission merchant to offset the net liability positions in full.

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, 2014:

Currency Swaps Outstanding At September 30, 2014
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 transaction gain on the Bond liability is offset by a currency exchange loss on the swap contract.  Conversely, when the dollar weakens against the British pound sterling, the transaction loss on the Bond liability is offset by an exchange gain on the swap contract.  All such exchange gains or losses on the Bond liability are included in Long-term debt, net.  The offsetting exchange losses or gains on the swap contracts are recognized in Accumulated other comprehensive income (loss).  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.

Derivatives Not Receiving Hedge Accounting Treatment

Interest Rate Derivatives.  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 the transactions settle. The values of these derivatives are included in Other long-term assets or 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 2014 and 2013, the changes in market value of the interest rate derivatives resulted in deferred unrealized gains (losses) of $(149) million and $524 million, respectively.  There were no realized gains or losses for the years ended 2014 and 2013.

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. At September 30, 2014, and September 30, 2013, TVA's coal contract derivatives had net market values of $(86) million and $(140) million, respectively, which TVA deferred as regulatory assets or liabilities on a gross basis.  At September 30, 2014, TVA's coal contract derivatives had terms of up to three years.

The total market value of natural gas derivative contracts was $(10) million at September 30, 2014, and $(1) million at September 30, 2013. At September 30, 2014, natural gas derivative contracts had terms of up to two years.

Commodity Contract Derivatives At September 30
	2014					2013
	Number ofContracts	Notional Amount	Fair Value (MtM)			Number of Contracts	Notional Amount	Fair Value (MtM)
Coal contract derivatives	24	31 million tons	$	(86	)	19	43 million tons	$	(140	)
Natural gas contract derivatives	46	62 million mmBtu	$	(10	)	13	39 million mmBtu	$	(1	)

Derivatives Under FTP. While TVA is currently evaluating the use of financial instruments for price hedging, certain natural gas futures and swaps remain as part of the suspended FTP.TVA has a FTP under which it may purchase and sell futures, swaps, options, and combinations of these instruments (as long as they are standard in the industry) to hedge TVA’s exposure to (1) the price of natural gas, fuel oil, electricity, coal, emission allowances, nuclear fuel, and other commodities included in TVA’s fuel cost adjustment calculation, (2) the price of construction materials, and (3) contracts for goods priced in or indexed to foreign currencies. The combined transaction limit for the fuel cost adjustment and construction material transactions is $130 million (based on one-day value at risk). In addition, the maximum hedge volume for the construction material transactions is 75 percent of the underlying net notional volume of the material that TVA anticipates using in approved TVA projects, and the market value of all outstanding hedging transactions involving construction materials is limited to $100 million at the execution of any new transaction. The portfolio value at risk limit for the foreign currency transactions is $5 million and is separate and distinct from the $130 million transaction limit discussed above. TVA's policy prohibits trading financial instruments under the FTP for speculative purposes.

At September 30, 2014 and 2013, the risks hedged under the FTP were the economic risks associated with the prices of natural gas, fuel oil, and crude oil. At September 30, 2014 and 2013, TVA had no outstanding coal contract derivatives under the FTP. There were no futures contracts or options contracts outstanding under the FTP at September 30, 2014, and swap contracts under the FTP had remaining terms of three years or less.

Derivatives under Financial Trading Program At September 30
	2014				2013
	Notional Amount	Fair Value (MtM) (in millions)			Notional Amount	Fair Value (MtM) (in millions)
Natural gas (in mmBtu)
Futures contracts	—	$	—		—	$	—
Swap contracts	102,227,500	(103		)	152,922,500	(169		)
Option contracts	—	—			—	—
Natural gas financial positions	102,227,500	$	(103	)	152,922,500	$	(169	)
Fuel oil/crude oil (in barrels)
Futures contracts	—	$	—		—	$	—
Swap contracts	—	—			1,205,000	3
Option contracts	—	—			—	—
Fuel oil/crude oil financial positions	—	$	—		1,205,000	$	3

Note

Due to the right of setoff and method of settlement, TVA elects to record commodity derivatives under the FTP based on its net commodity position with the broker or other counterparty.  Notional amounts disclosed represent the net absolute value of contractual amounts.

TVA defers all FTP unrealized gains (losses) as regulatory liabilities (assets) and records realized gains or losses to match the delivery period of the derivative contract. In addition to the open commodity derivatives disclosed above, TVA had closed derivative contracts with market values of $(5) million at September 30, 2014, and $(8) million at September 30, 2013. TVA experienced the following unrealized and realized gains and losses related to the FTP at the dates and during the periods, as applicable, set forth in the tables below:

Financial Trading Program Unrealized Gains (Losses) At September 30
FTP unrealized gains (losses) deferred as regulatory liabilities (assets)	2014			2013
Natural gas	$	(103	)	$	(169	)
Fuel oil/crude oil	—			3
Coal	—			—

Financial Trading Program Realized Gains (Losses) For the years ended September 30
Decrease (increase) in fuel expense	2014			2013
Natural gas	$	(34	)	$	(78	)
Fuel oil/crude oil	2			4
Coal	—			(1		)

Financial Trading Program Realized Gains (Losses) For the years ended September 30
Decrease (increase) in purchased power expense	2014			2013
Natural gas	$	(11	)	$	(51	)

Offsetting of Derivative Assets and Liabilities

The amounts of TVA's derivative instruments as reported in the Consolidated Balance Sheets as of September 30, 2014, and September 30, 2013, are shown in the table below.

	As of September 30, 2014
	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
Currency swaps	$	64		$	(64	)	$	—
Commodity derivatives under FTP	51			(51		)	—
Total derivatives subject to master netting or similar arrangement	115			(115		)	—
Total derivatives not subject to master netting or similar arrangement	1			—			1
Total	$	116		$	(115	)	$	1
Liabilities
Currency swap (3)	$	(15	)	$	—		$	(15	)
Interest rate swaps (3)	(1,348		)	—			(1,348		)
Commodity derivatives under FTP	(154		)	120			(34		)
Total derivatives subject to master netting or similar arrangement	(1,517		)	120			(1,397		)
Total derivatives not subject to master netting or similar arrangement	(97		)	—			(97		)
Total	$	(1,614	)	$	120		$	(1,494	)
	As of September 30, 2013
	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
Currency swaps	$	61		$	(33	)	$	28
Commodity derivatives under FTP	101			(98		)	3
Total derivatives subject to master netting or similar arrangement	162			(131		)	31
Total derivatives not subject to master netting or similar arrangement	3			—			3
Total	$	165		$	(131	)	$	34
Liabilities
Currency swap (3)	$	(15	)	$	—		$	(15	)
Interest rate swaps (3)	(1,199		)	—			(1,199		)
Commodity derivatives under FTP	(267		)	198			(69		)
Total derivatives subject to master netting or similar arrangement	(1,481		)	198			(1,283		)
Total derivatives not subject to master netting or similar arrangement	(144		)	—			(144		)
Total	$	(1,625	)	$	198		$	(1,427	)

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 which are not offset in the balance sheets.

(3) Letters of credit of approximately $1.0 billion and $800 million were posted as collateral at September 30, 2014 and September 30, 2013, 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 LTDCP.  All securities in the trusts are classified as trading.  See Note 16 — Investments Funds for a discussion of the trusts' objectives and the types of investments included in the various trusts.  These trusts may invest in derivative instruments which may include swaps, futures, options, forwards, and other instruments.  At September 30, 2014, and September 30, 2013, the fair value of derivative instruments in these trusts was not material to TVA's consolidated financial statements.

Collateral.  TVA's interest rate swaps, currency swaps, and commodity derivatives under the FTP 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, 2014, the aggregate fair value of all derivative instruments with credit-risk related contingent features that were in a liability position was $1.4 billion.  TVA's collateral obligations at September 30, 2014, under these arrangements, was $900 million, for which TVA had posted $1.0 billion in letters of credit.  These letters of credit reduce the available balance under the related credit facilities.  TVA's assessment of the risk of its nonperformance includes a reduction in its exposure under the contract as a result of this posted collateral.

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

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

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

Counterparty Credit Risk

Credit risk is the exposure to economic loss that would occur as a result of a counterparty's nonperformance of its contractual obligations.  Where exposed to counterparty credit 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 employs credit mitigation measures, such as collateral or prepayment arrangements and master purchase and sale agreements, to mitigate credit risk.

Credit of Customers.  The majority of TVA's counterparty credit risk is associated with trade accounts receivable from delivered power sales to LPCs, all located in the Tennessee Valley region.  To a lesser extent, TVA is exposed to credit risk from directly served industries and federal agencies, and 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 had concentrations of accounts receivable from three customers that represented 27 percent of total outstanding accounts receivable at September 30, 2014 and 2013.

Credit of Derivative Counterparties.  TVA has entered into derivative contracts for hedging purposes, and TVA's NDT fund and qualified defined benefit pension plan have entered into derivative contracts for investment purposes.  If a counterparty to one of TVA's hedging transactions defaults, TVA might incur substantial costs in connection with entering into a replacement hedging transaction.  If a counterparty to the derivative contracts into which the NDT fund and the pension plan have entered for investment purposes defaults, the value of the investment could decline significantly or perhaps become worthless.  TVA has concentrations of credit risk from the banking and coal industries because multiple companies in these industries serve as counterparties to TVA in various derivative transactions.  At September 30, 2014, all of TVA's currency swaps, interest rate swaps, and commodity derivatives under the FTP were with counterparties whose Moody's credit rating was Baa2 or higher.  At September 30, 2014, all of TVA's coal contract derivatives were with counterparties whose Moody's credit rating, or TVA's internal analysis when such information was unavailable, was Caa1 or higher. See Derivatives Not Receiving Hedge Accounting Treatment.

TVA currently utilizes two active futures commission merchants ("FCMs") to clear commodity contracts, including futures, options, and similar financial derivatives. These transactions are executed under the FTP by the FCMs on exchanges on behalf of TVA. TVA maintains margin cash accounts with the FCMs. See notes to the Mark-to-Market Values of TVA Derivatives table.

Credit of 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 money that it paid to the supplier under the contract and have to purchase replacement fuel or power on the spot market, perhaps at a significantly higher price than TVA was entitled to pay under the contract.  In addition, TVA might not be able to acquire replacement fuel or power in a timely manner and thus might be unable to satisfy its own obligations to deliver power.  To help ensure a reliable supply of coal, TVA had coal contracts with multiple suppliers at September 30, 2014.  The contracted supply of coal is sourced from multiple geographic regions of the United States and is to be delivered via various transportation methods (for example, barge, rail, and truck).  TVA purchases the majority of its natural gas requirements from a variety of suppliers under short-term contracts.

TVA has a power purchase agreement that expires on March 31, 2032, with a supplier of electricity for 440megawatts ("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.

XML

Commitments and Contingencies Commitments and Contingencies - Debt (Details) (USD $)	12 Months Ended
	Sep. 30, 2014 variable_interest_entities	Sep. 30, 2013	Aug. 09, 2013
Debt Instrument
Remaining terms of the agreements, high end of range	18 years
Outstanding discount notes	$ 596,000,000
Outstanding long-term debt including current maturities)	23,000,000,000
Long-term and short-term debt combined	23,600,000,000
Number of VIEs	3
Outstanding long-term debt (including current maturities) of VIEs	1,300,000,000
Membership interests of VIE subject to mandatory redemption	$ 50,000,000	$ 50,000,000	$ 40,000,000

XML

Benefit Plans

12 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

Benefit Plans

Benefit Plans

TVA sponsors a qualified defined benefit pension plan that covers most of its full-time employees, a qualified defined contribution 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.

Overview of Plans and Benefits

Retirement Plans.  TVA sponsors a qualified defined benefit pension plan and a qualified defined contribution 401(k) plan for most of its full-time annual employees hired prior to July 1, 2014, that provides two benefit structures: the Original Benefit Structure and the Cash Balance Benefit Structure. Eligible employees initially hired on or after January 1, 1996, must participate in the Cash Balance Benefit Structure. On April 11, 2014, the Tennessee Valley Authority Retirement System ("TVARS") Board approved amendments to the qualified defined benefit plan effective June 30, 2014. These amendments closed the defined benefit plan to new employees and certain rehires hired on or after July 1, 2014. These employees will be eligible for a retirement benefit as participants in the Employer Automatic Benefit Structure and will be eligible for a defined contribution benefit in the 401(k) plan only. A summary of the benefits provided by each structure is as follows:

• Original Benefit Structure.  The pension benefit for a member participating in the Original Benefit Structure is based on the member’s creditable service, the member’s average monthly salary for the highest three consecutive years of eligible compensation, and a pension factor based on the member’s age and years of service, less a Social Security offset. In addition, TVA makes matching contributions of 25 cents on the dollar (up to 1.5 percent of eligible compensation) to the 401(k) plan for members participating in the Original Benefit Structure.

• Cash Balance Benefit Structure.  The pension benefit for a member participating in the Cash Balance Benefit Structure is based on credits accumulated in the member’s account and the member’s age.  A member’s account receives pay credits equal to six percent of his or her eligible compensation.  The account also receives interest credits at a rate set at the beginning of each calendar year equal to the change in the Consumer Price Index for All Urban Consumers ("CPI-U") plus three percent, with the provision that the rate may not be less than six percent or more than ten percent.  The interest crediting rate was six percent for calendar years 2014 and 2013. In addition, TVA makes matching contributions of 75 cents on the dollar (up to 4.5 percent of eligible compensation) to the 401(k) plan for members participating in the Cash Balance Benefit Structure.

• Employer Automatic Benefit Structure. Members participating in the Employer Automatic Benefit Structure receive an automatic, non-elective contribution by TVA to the 401(k) plan equal to 4.5 percent of eligible compensation and matching contributions by TVA to the 401(k) plan of 75 cents on the dollar (up to 4.5 percent of eligible compensation).

There are two investment funds within the defined benefit pension plan: the Fixed Benefit Fund and the Variable Fund.  TVA's plan contributions are deposited in the Fixed Benefit Fund.  Eligible employees in the Original Benefit Structure and Cash Balance Benefit Structure are allowed to make voluntary contributions to either the Variable Fund, the Fixed Fund within the Fixed Benefit Fund, or both.  Employee contributions are limited to $10,000 per year per eligible employee. The pension plan pays interest at the lesser of six percent or the actuarial assumed rate of return less 0.5 percent to employees in the Fixed Fund.  Employee contributions in the Fixed Fund were credited an annual rate of interest of six percent during 2014 and 2013, resulting in credit amounts of $33 million and $36 million, respectively.  Employee contributions to the Variable Fund are invested in an S&P 500 Stock Index Fund. 

The defined benefit pension plan and the defined contribution 401(k) plan are administered by a separate legal entity, TVARS, which is governed by its own board of directors (the "TVARS Board").  Upon notification by the TVARS Board of the minimum required and recommended contributions, TVA determines the level of contribution to make to TVARS to fund the defined benefit pension plan for the upcoming fiscal year.

In 2009, changes were made to the cost of living adjustment ("COLA") provisions of the defined benefit pension plan. The eligibility for the COLA became age 60 for employees who retire on or after January 1, 2010. In addition, the COLA was subject to caps for calendar years 2010 to 2013. As a result, the COLA for eligible retirees for the four years beginning January 1, 2010 were as follows:

•For CY 2010, the COLA was zero.

•For CY 2011, the COLA was 1.15 percent.

•For CY 2012, the COLA was zero.

•For CY 2013, the COLA was 2.3 percent.

In CY 2014, the COLA benefit of CPI-U, capped at 5.0 percent, was restored and was 1.53 percent.

Members of both the Original Benefit Structure and the Cash Balance Benefit Structure can also become eligible for a supplemental pension benefit based on age and years of service at retirement, which is designed to help offset the cost of retiree medical insurance.

401(k) Plan Contributions. TVA made non-elective and matching contributions of approximately $35 million to the plan during 2014, $34 million during 2013, and $34 million during 2012.

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.  TVA has historically funded the annual calculated expense.

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.

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 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, net actuarial gains or losses, and the funded status as regulatory assets as such amounts are probable of collection in future rates. In 2015, TVA began including its cash contributions to the pension plan in the rate-making formula; accordingly, on October 1, 2014, TVA began recognizing pension costs as regulatory assets to the extent that the amount calculated under GAAP as pension expense differs from the amount TVA contributes to the pension plan.

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 active employees.

Asset Method.  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.  Since the “market-related” value of assets recognizes investment gains and losses over a three-year period, the future value of assets will be impacted as previously deferred gains or losses are recognized.  The “market-related” value is used in calculating expected return on plan assets and net gain or loss for pension cost determination.

Obligations and Funded Status

The changes in plan obligations, assets, and funded status for the years ended September 30, 2014 and 2013, were as follows:

Obligations and Funded Status For the years ended September 30
	Pension Benefits						Other Post-Retirement Benefits
	2014			2013			2014			2013
Change in benefit obligation
Benefit obligation at beginning of year	$	11,471		$	11,995		$	656		$	811
Service cost	130			154			18			24
Interest cost	558			468			32			31
Plan participants’ contributions	28			29			—			—
Collections(1)	—			—			93			79
Amendments	2			4			—			—
Actuarial loss (gain)	722			(549		)	(21		)	(163		)
Net transfers from variable fund/401(k) plan	13			4			—			—
Expenses paid	(6		)	(6		)	—			—
Benefits paid	(653		)	(628		)	(126		)	(126		)
Benefit obligation at end of year	12,265			11,471			652			656
Change in plan assets
Fair value of net plan assets at beginning of year	7,221			7,029			—			—
Actual return on plan assets	648			787			—			—
Plan participants’ contributions	28			29			—			—
Collections(1)	—			—			93			79
Net transfers from variable fund/401(k) plan	13			4			—			—
Employer contributions(2)	256			6			33			47
Expenses paid	(6		)	(6		)	—			—
Benefits paid	(653		)	(628		)	(126		)	(126		)
Fair value of net plan assets at end of year	7,507			7,221			—			—
Funded status	$	(4,758	)	$	(4,250	)	$	(652	)	$	(656	)

Notes

(1) Collections include retiree contributions as well as federal reinsurance payments and provider discounts and rebates.

(2) Other Post-Retirement Benefits Employer contributions are reduced by federal reinsurance payments and provider discounts and rebates.

The pension actuarial loss above for 2014 primarily reflects the impact of the decrease in the discount rate from 5.00 percent to 4.45 percent, which increased the liability by approximately $729 million. Additional losses were due to demographic experience from the impact of TVA’s organizational restructuring in 2014. This increased the projected benefit obligation by $36 million. These losses were partially offset by the $88 million gain from the change in the retirement rates assumptions based on a five-year experience study.

The pension actuarial gain above for 2013 primarily reflects the impact of the increase in the discount rate from 4.00 percent to 5.00 percent, which decreased the liability by approximately $1.4 billion.  The actuarial gain was partially offset by the impact of including certain retiree benefits in the pension obligation which were not considered in prior periods, which increased the 2013 liability by $705 million.

The $21 million other post-retirement actuarial gain for 2014 was primarily due to demographic experience related to updated per capita claims costs and retiree contributions, which decreased the liability by $64 million. The change in the retirement rates assumptions provided an additional gain of $16 million. These gains were partially offset by the decrease in the discount rate from 5.05 percent to 4.50 percent and the reduction in force impact, which increased the obligation by $43 million and $17 million, respectively.

The other post-retirement actuarial gain for 2013 primarily reflects the impact of the increase in the discount rate from 4.00 percent to 5.05 percent, which decreased the liability by $93 million. Additional gains were due to demographic experience related to per capita costs, contributions, participation rates, and changes in plan provisions, which decreased the liability by $43 million. Changes in the adjustment of the impact of the excise tax assumption decreased the liability by $33 million. These decreases in the post-retirement liability were slightly offset by the change in the COLA and mortality assumptions.

Amounts related to these benefit plans recognized on TVA's consolidated balance sheets consist of regulatory assets that have not been recognized as components of net periodic benefit cost at September 30, 2014 and 2013, 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
	2014			2013			2014			2013
Regulatory assets	$	4,157		$	3,910		$	140		$	166
Accounts payable and accrued liabilities	(5		)	(5		)	(38		)	(39		)
Pension and post-retirement benefit obligations(1)	(4,753		)	(4,245		)	(614		)	(617		)

Note

(1) Table above excludes $472 million and $486 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, 2014 and 2013, respectively.

Unrecognized amounts included in regulatory assets yet to be recognized as components of accrued benefit cost at September 30 consisted of:

Post-retirement Benefit Costs Deferred as Regulatory Assets At September 30
	Pension Benefits						Other Post-Retirement Benefits
	2014			2013			2014			2013
Unrecognized prior service cost (credit)	$	(180	)	$	(203	)	$	(39	)	$	(45	)
Unrecognized net loss	4,337			4,113			179			211
Total regulatory assets	$	4,157		$	3,910		$	140		$	166

The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for the pension plan at September 30, 2014, and 2013, were as follows:

Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets At September 30
	2014		2013
Projected benefit obligation	$	12,265	$	11,471
Accumulated benefit obligation	12,039		11,216
Fair value of net plan assets	7,507		7,221

The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the years ended September 30, 2014, and 2013, were as follows:

Components of Net Periodic Benefit Cost For the years ended September 30
	Pension Benefits									Other Post-Retirement Benefits
	2014			2013			2012			2014			2013			2012
Service cost	$	130		$	154		$	139		$	18		$	24		$	19
Interest cost	558			468			490			32			31			35
Expected return on plan assets	(435		)	(428		)	(437		)	—			—			—
Amortization of prior service credit	(21		)	(22		)	(23		)	(6		)	(6		)	(6		)
Recognized net actuarial loss	285			377			361			11			25			29
Total net periodic benefit cost recognized	$	517		$	549		$	530		$	55		$	74		$	77

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 2015 At September 30, 2014
	Pension Benefits			Other Post-Retirement Benefits			Total
Prior service cost (credit)	$	(21	)	$	(6	)	$	(27	)
Net actuarial loss	277			8			285

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 At September 30
	Pension Benefits				Other Post-Retirement Benefits
	2014		2013		2014		2013
Assumptions utilized to determine benefit obligations at September 30
Discount rate	4.45	%	5.00	%	4.50	%	5.05	%
Rate of compensation increase	5.70	%	5.72	%	N/A		N/A
Initial health care cost trend rate	N/A		N/A		7.50	%	8.00	%
Ultimate health care cost trend rate	N/A		N/A		5.00	%	5.00	%
Ultimate trend rate is reached in year beginning	N/A		N/A		2019		2019
Assumptions utilized to determine net periodic benefit cost for the years ended September 30
Discount rate	5.00	%	4.00	%	5.05	%	4.00	%
Expected return on plan assets	7.25	%	7.25	%	N/A		N/A
Rate of compensation increase	5.72	%	4.44	%	N/A		N/A
Initial health care cost trend rate	N/A		N/A		8.00	%	8.50	%
Ultimate health care cost trend rate	N/A		N/A		5.00	%	5.00	%
Ultimate trend rate is reached in year beginning	N/A		N/A		2019		2019

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. Based on recent market trends, TVA decreased its discount rate used to determine the pension benefit obligation and other post-retirement benefit obligation. At September 30, 2014, the discount rates used to determine the pension and other post-retirement benefit obligations for 2014 were 4.45 percent and 4.50 percent, respectively. At September 30, 2013, the discount rates used to determine the pension and other post-retirement benefit obligations were 5.00 percent and 5.05 percent, respectively. The discount rate assumptions used to determine the obligations at year-end are used to determine the net periodic benefit costs for the following year.

Rate of Return.  The qualified defined benefit pension plan is the only plan that is funded with qualified plan

assets. In determining its 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 and asset class factors. 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 current asset allocation policy approved by the TVARS Board 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 change in the funded status of TVARS. Changes in the expected return rates are based on annual studies performed by third party professional investment consultants. Based upon the results from the 2014 annual study, TVA adjusted the assumption from 7.25 percent that was used to measure the 2014, 2013, and 2012 net periodic pension benefit cost, to a 7.00 percent expected rate of return that will be used to measure the 2015 net periodic benefit 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 2013 and determined that future compensation would likely increase at rates between 3.50 percent and 13.00 percent per year, depending upon the employee's age. Based upon the current active participants, the average assumed compensation increase used to determine benefit obligations for 2014 and 2013 was 5.70 percent and 5.72 percent, respectively. The average assumed compensation increase to determine net periodic pension benefit costs for 2014, 2013, and 2012 were 5.72 percent, 4.44 percent, and 4.43 percent, respectively.

Mortality.  Mortality assumptions are based on the results obtained from a recent actual company experience study performed, which included retirees as well as other plan participants. TVA obtained an updated study in 2013, which indicated an improvement in TVA's mortality experience. Accordingly, TVA adjusted the projection period for the RP-2000 Mortality Tables for males and females projected to 2022 using scale AA at September 30, 2013. Additional experience per the actuarial review in 2014 indicated that actual experience remains in line with the assumption adopted in 2013. Therefore, TVA maintained this assumption for 2014. At September 30, 2012, the projection period for the RP- 2000 Mortality Tables for males and females was projected to 2013 using scale AA.

Health Care Cost Trends. TVA reviews actual recent cost trends and projected future trends in establishing health care cost trend rates. The assumed health care trend rates used to determine post-retirement benefit obligations for 2014 and 2013 were 7.50 percent and 8.00 percent, respectively. The 2014 health care cost trend rate of 7.50 percent used to determine post-retirement benefit obligations is assumed to gradually decrease each successive year until it reaches a 5.00 percent annual increase in health care costs in the years beginning October 1, 2019, and beyond. The assumed health care cost trend rates used to determine the net periodic post-retirement cost were 8.00 percent for 2014, 8.50 percent for 2013, and 8.00 percent for 2012. TVA plans to use 7.50 percent in the determination of 2015 net periodic post-retirement cost. TVA had increased the rate from 2012 to 2013 based upon exhibited annual increases in costs per covered life due primarily to changes in inflation, utilization, and healthcare regulations. Costs in 2014 have decreased in line with the actuarial expectations as a result of plan changes and prescription drug coverage.

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 may receive a COLA on the base pension portion of the monthly pension benefit 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. The minimum COLA is one percent and the maximum is five percent. The COLA was temporarily reduced for a four-year period beginning January 1, 2010, for current retirees, and the eligibility for the COLA was changed to age 60 from attained age 55 for employees retiring on or after January 1, 2010. The COLA assumption was 2.50 percent from 2009 to 2012; however, in 2013, TVA adjusted the COLA assumption due to the Federal Reserve System’s long-term monetary policy and the market-based expectations that inflation will remain below two percent into 2015. TVA adjusted the COLA assumption at September 30, 2013, to 1.6 percent with an assumed gradual increase each successive year until it reaches 2.50 percent in 2020. At September 30, 2014, the COLA is assumed to increase to 2.0 percent with an assumed gradual increase each successive year until it reaches 2.50 percent in 2020.

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, 2014
Actuarial Assumption	Change in Assumption		Impact on 2014 Pension Cost		Impact on 2014 Projected Benefit Obligation
Discount rate	(0.25	)	$	18	$	369
Rate of return on plan assets	(0.25	)	15		N/A

Each fluctuation above assumes that the other components of the calculation are held constant and excludes any impact for unamortized actuarial gains or losses.

The following chart reflects the sensitivity of post-retirement benefit cost to changes in the health care trend rate:

Sensitivity to Changes in Assumed Health Care Cost Trend Rates At September 30, 2014
	1% Increase		1% Decrease
Effect on total of service and interest cost components for the year	$	7	$	(7	)
Effect on end-of-year accumulated post-retirement benefit obligation	89		(93		)

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 qualified defined benefit pension plan (the "Plan"), which includes the Original Benefit Structure and the Cash Balance Benefit Structure, is the only plan that includes qualified plan assets. TVARS has a long-term investment plan which contains a dynamic de-risking strategy that allocates investments to assets that better match the liability, such as long duration fixed income securities, over time as funding status targets are met. The investment asset allocation policy approved by the TVARS Board has targets of 47 percent equity including U.S., non-U.S., private, and low volatility global public equity investments, 28 percent fixed income securities, 15 percent public real assets including Treasury Inflation-Protected Securities ("TIPS"), commodities, and Master Limited Partnerships ("MLPs"), and 10 percent private real assets. The qualified pension plan assets are invested across global public equity, private equity, cash, core fixed income, long-term core fixed income, investment grade credit, high yield fixed income, emerging markets fixed income, global TIPS, commodities, MLPs, and private real assets. The TVARS asset allocation policy includes permissible deviations from these target allocations. The TVARS Board can take action, as appropriate, to rebalance the system’s assets consistent with the asset allocation policy. At September 30, 2014 and 2013, the asset holdings of the system included the following:

Asset Holdings of TVARS At September 30
			Plan Assets at September 30
Asset Category	Target Allocation		2014		2013
Global equity	32	%	43	%	48	%
Private equity	10	%	5	%	6	%
Low volatility global public equity	5	%	1	%	—	%
Cash	2	%	2	%	2	%
Core fixed income	5	%	5	%	5	%
Long-term core fixed income	5	%	5	%	4	%
Investment grade credit	6	%	6	%	6	%
International emerging markets fixed income	5	%	5	%	—	%
High yield fixed income	5	%	6	%	10	%
Global TIPS	5	%	5	%	7	%
Private real assets	10	%	7	%	7	%
Commodities	5	%	4	%	—	%
MLPs	5	%	6	%	5	%
Total	100	%	100	%	100	%

Fair Value Measurements

The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2014:

TVA Retirement System At September 30, 2014
	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	$	1,669	$	1,668	$	—	$	1
Preferred securities	37		5		32		—
Debt securities
Corporate debt securities	1,326		—		1,304		22
Residential mortgage-backed securities	204		—		201		3
Debt securities issued by U.S. Treasury and other U.S. government agencies	93		93		—		—
Debt securities issued by foreign governments	225		—		218		7
Asset-backed securities	176		—		147		29
Debt securities issued by state/local governments	30		—		29		1
Commercial mortgage-backed securities	23		—		20		3
Commingled Funds
Equity	1,106		—		1,106		—
Debt	661		—		661		—
Commodity	332		—		332		—
Blended	228		—		228		—
Institutional mutual funds	28		28		—		—
Cash equivalents and other short-term investments	464		—		464		—
Certificates of deposit	19		—		19		—
Private equity funds	481		—		—		481
Private real estate funds	435		—		334		101
Treasury bills, U.S. Government notes, and securities held as futures and other derivative collateral	35		10		25		—
Securities lending commingled funds	2		—		2		—
Derivatives
Purchased options	18		—		18		—
Foreign currency forward receivable	8		—		8		—
Total Assets	$	7,600	$	1,804	$	5,148	$	648
Liabilities
Derivatives
Futures	11		$	11	$	—	$	—
Foreign currency forward payable	8		—		8		—
Written option obligations	7		—		7		—
Total Liabilities	$	26	$	11	$	15	$	—

Notes

(1) Excludes approximately $65 million in net payables associated with security purchases and sales and various other payables.

(2) Excludes a $2 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

The following table provides the fair value measurement amounts for assets held by TVARS at September 30, 2013:

TVA Retirement System At September 30, 2013
	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	$	1,689	$	1,686	$	—	$	3
Preferred securities	22		17		—		5
Debt securities
Corporate debt securities	1,352		—		1,334		18
Residential mortgage-backed securities	355		—		352		3
Debt securities issued by U.S. Treasury and other U.S. government agencies	113		113		—		—
Debt securities issued by foreign governments	31		—		30		1
Asset-backed securities	120		—		110		10
Debt securities issued by state/local governments	36		—		36		—
Commercial mortgage-backed securities	21		—		18		3
Commingled Funds
Equity	1,182		—		1,182		—
Debt	786		—		786		—
Blended	263		—		263		—
Institutional mutual funds	26		26		—		—
Cash equivalents and other short-term investments	395		1		394		—
Private equity funds	528		—		—		528
Private real estate funds	382		—		297		85
Treasury bills, U.S. Government notes, and securities held as futures and other derivative collateral	39		8		31		—
Securities lending commingled funds	3		—		3		—
Derivatives
Foreign currency forward receivable	6		—		6		—
Purchased options	6		—		6		—
Credit default swaps	4		—		4		—
Written option obligations	4		4		—		—
Total Assets	$	7,363	$	1,855	$	4,852	$	656
Liabilities
Derivatives
Foreign currency forward payable	$	6	$	—	$	6	$	—
Credit default swaps	1		—		1		—
Written option obligations	1		—		1		—
Total Liabilities	$	8	$	—	$	8	$	—

Notes

(1) Excludes approximately $131 million in net payables associated with security purchases and sales and various other payables.

(2) Excludes a $3 million payable for collateral on loaned securities in connection with TVARS’s participation in securities lending programs.

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, 2012	$	633
Net realized/unrealized gains (losses)	45
Purchases, sales, issuances, and settlements (net)	(21		)
Transfers in and/or out of Level 3	(1		)
Balance at September 30, 2013	656
Net realized/unrealized gains (losses)	50
Purchases, sales, issuances, and settlements (net)	(53		)
Transfers in and/or out of Level 3	(5		)
Balance at September 30, 2014	$	648

The following descriptions of the valuation methods and assumptions used by the Plan to estimate the fair value of investments apply to investments held directly by the Plan. Third-party pricing vendors provide valuations for investments held by the Plan in most instances, except for commingled, private equity, and private real estate funds which are priced at net asset values established by the investment managers with possible adjustment by management to reflect estimated current fair value. In instances where pricing is determined to be based on unobservable inputs, or where liquidity restrictions exist in the case of funds valued at net asset value, a Level 3 classification has been assigned.

Equities and Preferred Securities. Investment securities, including common stock, mutual funds, and preferred securities 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. If there are no current day sales, the securities are valued at their last quoted bid price. Equities and preferred securities priced by an exchange in an active market are classified as Level 1. 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.

Corporate Debt Securities. Most 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 developed by sources considered by management to be reliable. 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).

Residential Mortgage-Backed Securities. Residential mortgage-backed securities consist of collateralized mortgage obligations ("CMOs") and U.S. pass-through security pools related to government-sponsored enterprises ("GSE"). 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 GSE 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.

U.S. Treasury and Agency Securities. 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). Agency securities are typically priced using evaluated pricing applications and models incorporating U.S. Treasury yield curves. Agency securities are classified as Level 2 because of the nature of their market-data-based pricing models.

Debt Securities Issued by Foreign Governments. These include foreign government bonds and foreign government inflation-linked securities. They are typically priced based on proprietary discounted cash flow models, incorporating option-adjusted spread features as appropriate. Most debt securities issued by foreign governments are classified as Level 2 because of the nature of their market-data-based pricing models.

Asset-Backed Securities. 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, most asset-backed securities are classified as Level 2.

Debt Securities Issued by State and Local Governments. Most debt securities issued by state and local governments are 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.

Commercial Mortgage-Backed Securities. Commercial mortgage-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, most commercial mortgage-backed securities are classified as Level 2.

Commingled Funds. The 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 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 (Level 2 inputs). These net asset values may be adjusted by management if it is determined that they do not reflect a current estimate of fair value.

The 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, the S&P 500 index, and the Morgan Stanley Capital International All Country World Index ex-U.S. 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 Plan is invested in actively managed debt commingled funds which 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. The objective is to achieve a positive relative total return through active credit selection.

The 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 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 Plan’s investments in equity, debt, blended, and commodity commingled funds can generally be redeemed at any time upon notification of the investment managers, with required notice periods varying from same-day to monthly.

Institutional Mutual Funds. Participation units of institutional mutual funds are stated at their quoted redemption values as reported by the investment managers based on their net asset values, which reflect the fair values of the underlying investments. These funds are traded at published net asset values in an active market (Level 1 inputs).

Cash Collateral Held Under Securities Lending Arrangements. Fair value has been determined to approximate the deposit account balances held in cash collateral pools (Level 2 inputs), as no discounts for credit quality or liquidity were determined to be applicable.

Cash Equivalents and Other Short-Term Investments and Certificates of Deposit. Cash equivalents and other short-term investments are highly liquid securities with a maturity 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 Equity Funds. Private equity limited partnerships are reported at net asset values provided by the fund managers. These net asset values may be adjusted by management if it is determined that they do not reflect a current estimate of fair value.

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; 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. 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, and as such are classified as Level 3. Partnerships generally continue 10 to 12 years after the inception of the fund. The partnerships are subject to three to fourone-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 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 Plan’s private real estate investments are estimated utilizing net asset values provided by the investment managers. These net asset values may be adjusted by management if it is determined that they do not reflect a current estimate of fair value. The methodologies utilized by the investment managers to calculate their net asset values are summarized as follows:

The 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 Plan is invested in a commingled fund that develops, renovates, and re-leases real estate properties to create value. Investments are predominantly in top tier real estate markets that offer deep liquidity. Property types include residential, office, industrial, hotel, retail, and land. Properties are diversified by geographic region within the U.S. domestic market. The Plan is invested in a second commingled fund that invests primarily in core, well-leased, operating real estate properties with a focus on income generation. Investments are diversified by property type with a focus on office, industrial, apartment, and retail. Properties are diversified within the U.S. with an overweight to major market and coastal regions.

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 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.

The fair value hierarchy level classifications for the Plan’s real estate investments are determined based on redemption terms. Investments which cannot be redeemed at the measurement date, but which can be redeemed at a future date, are evaluated based on the length of time until the investment will become redeemable in determining whether the investment should be reported in either Level 2 or Level 3 of the fair value hierarchy. The redemption provisions vary by fund.

Derivatives. The Plan invests in a variety of derivative instruments. The valuation methodologies for these instruments are as follows:

Options. The 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.

Foreign currency forwards. The 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. Foreign currency forwards are disclosed on a net position basis.

Futures. The Plan enters into futures. The futures contracts are listed on either a national or foreign securities exchange and 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.

Swaps. The 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. 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. 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 Plan's swaps are generally classified as Level 2 based on the observable nature of their pricing inputs.

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 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.

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, 2014
	Pension Benefits		Other Post-Retirement Benefits
2015	$	712	$	39
2016	715		40
2017	720		41
2018	724		41
2019	731		41
2020 - 2024	3,759		186

Contributions.  In 2009, TVA made a contribution to TVARS of $1.0 billion for 2010 and as an advance on contributions for 2011 through 2013. In 2011, TVA made an additional discretionary contribution of $270 million to TVARS. In 2013 and 2012, the qualified defined pension plan's assets exceeded market return expectations and no discretionary contributions were made. The minimum contribution for 2014 was $198 million; however, TVA made a $250 million contribution to TVARS. The 2015 minimum contribution is $215 million; however, TVA expects to contribute $275 million to TVARS in 2015. In 2014, TVA made contributions of $6 million to the SERP and $47 million to the other post-retirement benefit plans. TVA expects to contribute $5 million to the SERP and $39 million to the other post-retirement benefit plans in 2015.

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 2.52 percent discount rate resulted in the recognition of approximately $34 million in expenses in 2014 and an unpaid benefit obligation of about $520 million at September 30, 2014. The 2014 current portion of the obligation is $48 million and is recorded in Accounts payable and accrued liabilities. The 2014 long-term portion of $472 million is recorded in Post-retirement and post-employment benefit obligations. The amounts in the current portion of the obligation represent the total unpaid losses and administrative fees for each year that are due one month following TVA’s fiscal year end.

The use of a 2.64 percent discount rate resulted in the recognition of approximately $(8) million in expenses in 2013 and an unpaid benefit obligation of about $535 million at September 30, 2013. The 2013 current portion of the obligation is $49 million and is recorded in Accounts payable and accrued liabilities. The 2013 long-term portion of $486 million is recorded in Post-retirement and post-employment benefit obligations. TVA utilized discount rates of 1.65 percent in 2012 resulting in expense of $52 million and a $597 million obligation.

The decrease in the unpaid benefit obligation from 2014 to 2013 is due primarily to the demographic experience gains from decreases in loss experiences and fewer claimants. The decrease in the unpaid benefit obligation and expense from 2012 to 2013 is due primarily to the increase in the discount rate from 1.65 percent in 2012 to 2.64 percent in 2013 resulting in a decrease of $45 million.  Decreases in loss experiences and other changes in demographic experiences also decreased the unpaid benefit obligation and expense to a lesser degree.

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Other Income (Expense), Net Other Income (Expense), Net (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Other Income (Expense), Net
Interest income	$ 23	$ 23	$ 21
External services	19	18	7
Gains (losses) on investments	6	4	5
Miscellaneous	1	(1)	0
Total other income (expense), net	$ 49	$ 44	$ 33

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Other Income (Expense), Net Other Income (Expense), Net (Tables)

12 Months Ended

Sep. 30, 2014

Other Income and Expenses [Abstract]

Other Income (Expense), Net

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

Other Income (Expense), Net For the years ended September 30
	2014		2013			2012
Interest income	$	23	$	23		$	21
External services	19		18			7
Gains (losses) on investments	6		4			5
Miscellaneous	1		(1		)	—
Total other income (expense), net	$	49	$	44		$	33

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Benefit Plans Sensitivity to Certain Changes in Pension Assumptions (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014
Discount rate
Defined Benefit Plan Disclosure
Change in Assumption	(0.25%)
Impact on Pension Cost	$ 18
Impact on Projected Benefit Obligation	369
Rate of return on plan assets
Defined Benefit Plan Disclosure
Change in Assumption	(0.25%)
Impact on Pension Cost	$ 15

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Regulatory Assets and Liabilities Regulatory Assets and Liabilities (Tables)

12 Months Ended

Sep. 30, 2014

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

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

Regulatory Assets and Liabilities At September 30
	2014		2013
Current regulatory assets
Unrealized losses on commodity derivatives	$	134	$	183
Deferred nuclear generating units	237		237
Environmental agreements	54		73
Fuel cost adjustment receivable	9		—
Environmental cleanup costs – Kingston ash spill	47		68
Total current regulatory assets	481		561
Non-current regulatory assets
Deferred pension costs and other post-retirement benefits costs	4,297		4,076
Unrealized losses on interest rate derivatives	957		808
Nuclear decommissioning costs	931		893
Environmental cleanup costs - Kingston ash spill	421		681
Non-nuclear decommissioning costs	645		571
Deferred nuclear generating units	1,255		1,438
Unrealized losses on commodity derivatives	72		139
Environmental agreements	108		189
Other non-current regulatory assets	308		336
Total non-current regulatory assets	8,994		9,131
Total regulatory assets	$	9,475	$	9,692
Current regulatory liabilities
Fuel cost adjustment tax equivalents	$	182	$	176
Fuel cost adjustment liability	—		29
Unrealized gains on commodity derivatives	2		7
Total current regulatory liabilities	184		212
Non-current regulatory liabilities
Unrealized gains on commodity derivatives	—		1
Total non-current regulatory liabilities	—		1
Total regulatory liabilities	$	184	$	213

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Benefit Plans Asset Holdings (Details)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Equity securities
Defined Benefit Plan Disclosure
New Policy Target Allocation	47.00%
Target Allocation	32.00%
Plan Asset Allocations	43.00%	48.00%
Private equity funds
Defined Benefit Plan Disclosure
Target Allocation	10.00%
Plan Asset Allocations	5.00%	6.00%
Low volatility global public equity [Member]
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	1.00%	0.00%
Cash and cash equivalents
Defined Benefit Plan Disclosure
Target Allocation	2.00%
Plan Asset Allocations	2.00%	2.00%
Core fixed income
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	5.00%	5.00%
Long-term core fixed income
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	5.00%	4.00%
Investment grade credit
Defined Benefit Plan Disclosure
Target Allocation	6.00%
Plan Asset Allocations	6.00%	6.00%
Foreign Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	5.00%	0.00%
High yield fixed income
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	6.00%	10.00%
Global TIPS
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	5.00%	7.00%
Private real assets
Defined Benefit Plan Disclosure
New Policy Target Allocation	10.00%
Target Allocation	10.00%
Plan Asset Allocations	7.00%	7.00%
Commodities
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	4.00%	0.00%
MLPs
Defined Benefit Plan Disclosure
Target Allocation	5.00%
Plan Asset Allocations	6.00%	5.00%
Fixed income
Defined Benefit Plan Disclosure
New Policy Target Allocation	28.00%
Public real assets
Defined Benefit Plan Disclosure
New Policy Target Allocation	15.00%

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CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL (USD $) In Millions, unless otherwise specified	3 Months Ended				12 Months Ended
	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Balance at beginning of year		$ 5,647		$ 5,326	$ 5,647	$ 5,326	$ 5,229
Net income (loss)	322	(67)	474	(245)	469	271	60
Total other comprehensive income (loss)					2	77	64
Return on power program appropriation investment					(4)	(7)	(7)
Return of power program appropriation investment					(10)	(20)	(20)
Balance at end of year	6,104		5,647		6,104	5,647	5,326
Power Program Appropriation Investment
Balance at beginning of year		268		288	268	288	308
Net income (loss)					0	0	0
Total other comprehensive income (loss)					0	0	0
Return on power program appropriation investment					0	0	0
Return of power program appropriation investment					(10)	(20)	(20)
Balance at end of year	258		268		258	268	288
Power Program Retained Earnings
Balance at beginning of year		4,767		4,492	4,767	4,492	4,429
Net income (loss)					477	282	70
Total other comprehensive income (loss)					0	0	0
Return on power program appropriation investment					(4)	(7)	(7)
Return of power program appropriation investment					0	0	0
Balance at end of year	5,240		4,767		5,240	4,767	4,492
Nonpower Programs Appropriation Investment, Net
Balance at beginning of year		609		620	609	620	630
Net income (loss)					(8)	(11)	(10)
Total other comprehensive income (loss)					0	0	0
Return on power program appropriation investment					0	0	0
Return of power program appropriation investment					0	0	0
Balance at end of year	601		609		601	609	620
Accumulated Other Comprehensive Income (Loss) Net Gains (Losses) on Cash Flow Hedges
Balance at beginning of year		3		(74)	3	(74)	(138)
Net income (loss)					0	0	0
Total other comprehensive income (loss)					2	77	64
Return on power program appropriation investment					0	0	0
Return of power program appropriation investment					0	0	0
Balance at end of year	$ 5		$ 3		$ 5	$ 3	$ (74)

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Fair Value Measurements Fair Value Measurements - Investments (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Investment Gains (Losses)
Investment fund securities classified as trading and measured at fair value	$ 2,000,000,000
Period of time where the investor contributes capital to an investment in a private partnership - minimum	3 years
Period of time where the investor contributes capital to an investment in a private partnership - maximum	4 years
Minimum investment period	10 years
NDT unfunded commitments related to private partnerships	113,000,000
Number of redemption or limited redemption options	0
Number of readily available quoted exchange prices for the investments	0
SERP
Investment Gains (Losses)
Unrealized gains (losses) on investments	1,000,000	2,000,000
LTDCP
Investment Gains (Losses)
Unrealized gains (losses) on investments	0	0
NDT
Investment Gains (Losses)
Unrealized gains (losses) on investments	35,000,000	48,000,000
ART
Investment Gains (Losses)
Unrealized gains (losses) on investments	15,000,000	33,000,000
Maximum
Investment Gains (Losses)
Equity investments not required to be measured at fair value	$ 1,000,000

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Accounts Receivable, Net

12 Months Ended

Sep. 30, 2014

Accounts Receivable, Net [Abstract]

Accounts Receivable, Net

Accounts Receivable, Net

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

Accounts Receivable, Net At September 30
	2014			2013
Power receivables	$	1,576		$	1,495
Other receivables	101			73
Allowance for uncollectible accounts	(1		)	(1		)
Accounts receivable, net	$	1,676		$	1,567

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Energy Prepayment Obligations and Discounts on Sales (Details) (USD $)	12 Months Ended				24 Months Ended		12 Months Ended			120 Months Ended	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2004	Sep. 30, 2004	Sep. 30, 2014 DEU [Member]	Sep. 30, 2014 MLGW	Sep. 30, 2013 MLGW	Sep. 30, 2012 MLGW	Sep. 30, 2014 MLGW	Sep. 30, 2014 Total	Sep. 30, 2013 Total	Sep. 30, 2012 Total
Energy Prepayment Obligations and Discounts on Sales
Incremental amount of discounted energy units	$ 1,000,000
Discount per kilowatt-hour	0.025
Discounted energy units contract period 1	5 years
Discounted energy units contract period 2	10 years
Discounted energy units contract period 3	15 years
Discounted energy units contract period 4	20 years
Total sales through DEU program since inception					55,000,000
Deferred Revenue						0
Deferred revenue, revenue recognized	1,000,000	2,000,000	5,000,000				100,000,000	100,000,000	100,000,000	1,100,000,000
Discounts reducing electricity sales											46,000,000	47,000,000	47,000,000
MLGW prepayment				1,500,000,000
MLGW prepayment period				180 months
Deferred revenue expected recognition each year							$ 100,000,000

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Risk Management Activities and Derivative Transactions Risk Management Activities and Derivative Transactions - Mark-to-Market Values of TVA Derivatives (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013
Derivatives, Fair Value
Derivative Liability, Fair Value, Gross Liability	$ 1,517		$ 1,481
Commodity derivatives under FTP
Derivatives, Fair Value
Fair value			0
Commodity derivatives under FTP | Other current assets
Derivatives, Fair Value
Derivative Liability, Fair Value, Gross Liability	69		100
200 million Sterling currency swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(15)		(15)
250 million Sterling currency swap | Other long-term assets
Derivatives, Fair Value
Fair value	56		51
150 million Sterling currency swap | Other long-term assets
Derivatives, Fair Value
Fair value	8		10
$1.0 billion notional interest rate swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(987)		(886)
$476 million notional interest rate swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(349)		(300)
$42 million notional interest rate swap | Other long-term liabilities
Derivatives, Fair Value
Fair value	(12)		(13)
Commodity contract derivatives
Derivatives, Fair Value
Fair value	(96)		(141)
Commodity contract derivatives | Other long-term assets
Derivatives, Fair Value
Fair value			1
Commodity contract derivatives | Other current assets
Derivatives, Fair Value
Fair value	1		2
Commodity contract derivatives | Other long-term liabilities
Derivatives, Fair Value
Fair value	(17)		(35)
Commodity contract derivatives | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	(80)		(109)
Derivatives Under FTP
Derivatives, Fair Value
Fair value	(103)	[1]	(166)	[1]
Derivatives Under FTP | Other current assets
Derivatives, Fair Value
Fair value	(69)		(97)
Derivatives Under FTP | Other long-term liabilities
Derivatives, Fair Value
Fair value	(14)		(36)
Derivatives Under FTP | Accounts payable and accrued liabilities
Derivatives, Fair Value
Fair value	$ (20)		$ (33)

[1] Fair values of certain derivatives under the FTP that were in net liability positions totaling $69 million and $100 million at September 30, 2014 and September 30, 2013, respectively, are recorded in TVA's margin cash accounts in Other current assets. These derivatives are transacted with futures commission merchants, and cash deposits have been posted to the margin cash accounts held with each futures commission merchant to offset the net liability positions in full.

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Benefit Plans Sensitivity to Changes in Assumed Health Care Cost Trend Rates (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014
Defined Benefit Plan Disclosure
Effect of one percentage point increase on total service and interest cost components	$ 7
Effect of one percentage point decrease on total service and interest cost components	(7)
Effect of one percentage point increase on end-of-year accumulated postretirement benefit obligation	89
Effect of one percentage point decrease on end-of-year accumulated postretirement benefit obligation	$ (93)

XML

Asset Retirement Obligations Asset Retirement Obligations (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013
Asset Retirement Obligations
Increase in ARO liability	$ (319)
Initial decommissioning estimate for nuclear	7 years
ARO-Nuclear Decommissioning Study Update	5 years
Accretion expense	40
Balance	3,488	[1]	3,289	[1]
Settlements (ash storage areas)	(14)	[1]	(37)	[1]
Asset Retirement Obligation, Revision of Estimate (Site Specific Studies)	(472)	[1]
Change in estimate	(10)	[1]	(66)	[1]
Accretion (recorded as regulatory asset)	177	[1]	170	[1]
Balance	3,169	[1]	3,488	[1]
Current portion of ARO	80
Nuclear
Asset Retirement Obligations
Balance	2,399	[1]	2,208	[1]
Settlements (ash storage areas)	0	[1]	0	[1]
Asset Retirement Obligation, Revision of Estimate (Site Specific Studies)	(472)	[1]
Change in estimate	0	[1]	(66)	[1]
Accretion (recorded as regulatory asset)	125	[1]	125	[1]
Balance	2,052	[1]	2,399	[1]
Non-nuclear
Asset Retirement Obligations
Balance	1,089	[1]	1,081	[1]
Settlements (ash storage areas)	(14)	[1]	(37)	[1]
Asset Retirement Obligation, Revision of Estimate (Site Specific Studies)	0	[1]
Change in estimate	(10)	[1]	0	[1]
Accretion (recorded as regulatory asset)	52	[1]	45	[1]
Balance	$ 1,117	[1]	$ 1,089	[1]

[1] The current portion of ARO in the amount of $80 million is included in Accounts payable and accrued liabilities.

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Commitments and Contingencies

12 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Commitments

At September 30, 2014, the amounts of contractual cash commitments maturing in each of the next five years and beyond are shown below:

Commitments and Contingencies Payments due in the years ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Debt(1)	$	1,628	$	32	$	1,555	$	1,682	$	1,032	$	17,692	$	23,621
Debt of VIEs	32		33		35		36		38		1,137		1,311
Membership interests of variable interest entity subject to mandatory redemption	2		2		2		2		2		29		39
Lease obligations
Capital	13		13		13		13		12		167		231
Non-cancelable operating	38		36		34		27		25		63		223
Purchase obligations
Power	220		222		232		235		239		3,364		4,512
Fuel	1,335		862		477		552		492		1,579		5,297
Other	304		215		202		199		192		1,640		2,752
Unfunded loan commitments	13		—		—		—		—		—		13
Payments on other financings	104		104		104		104		96		305		817
Total	$	3,689	$	1,519	$	2,654	$	2,850	$	2,128	$	25,976	$	38,816

Note

(1) Does not include noncash items of foreign currency exchange loss of $44 million and net discount on sale of Bonds of $89 million.

In addition to the cash requirements, above, TVA has contractual obligations in the form of revenue discounts related to energy prepayments.  See Note 1 — Energy Prepayment Obligations and Discounts on Sales.

Energy Prepayment Obligations Payments due in the years ending September 30
	2015		2016		2017		2018		2019		Thereafter		Total
Energy Prepayment Obligations	$	100	$	100	$	100	$	100	$	10	$	—	$	410

Debt. At September 30, 2014, TVA had outstanding discount notes of $596 million and long-term debt (including current maturities) at varying maturities and interest rates of $23.0 billion for total outstanding indebtedness of $23.6 billion. See Note 13.

Debt of VIEs. At September 30, 2014, TVA had outstanding long-term debt (including current maturities) attributable to its three VIEs of which it is the primary beneficiary of $1.3 billion. See Note 9.

Membership Interests of VIE Subject to Mandatory Redemption. At September 30, 2014, TVA had outstanding membership interests subject to mandatory redemption (including current portion) of $39 million issued by one of its VIEs of which it is the primary beneficiary. See Note 9.

Leases.  TVA leases certain property, plant, and equipment under agreements with terms ranging from one to 80 years.  Of the total obligations for TVA’s capital leases, $124 million represents the cost of financing.  TVA’s rental expense for operating leases was $75 million in 2014, $71 million in 2013, and $67 million in 2012.

Power Purchase Obligations.  TVA has contracted with various independent power producers and LPCs for additional capability to be made available to TVA. Several of these agreements have contractual minimum payments.  In total, these agreements provide 1,621 MW of summer net capability.  The remaining terms of the agreements range up to 18 years.  TVA incurred $293 million, $322 million, and $447 million of expense under power purchase agreements during 2014, 2013, and 2012, respectively.  Certain power purchase obligations are accounted for as capital leases. Costs under TVA’s power purchase agreements not 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, 2014, there was a combined qualifying capacity of 890 MW from six different suppliers, from which TVA purchased power under this law.  TVA’s obligations to purchase power from these qualifying facilities are not included in the Commitments and Contingencies table.

TVA, along with others, contracted with the Southeastern Power Administration ("SEPA") to obtain power and energy from eight U.S. Army Corps of Engineers hydroelectric facilities on the Cumberland River system.  The agreement with SEPA can be terminated upon three years’ notice, but this notice of termination may not become effective prior to June 30, 2017.  The contract requires SEPA to provide TVA an annual minimum of 1,500 hours of energy for each megawatt of TVA’s 405 MW allocation, and all surplus energy from the Cumberland River system.  TVA’s obligations under its contract with SEPA are not included in the Commitments and Contingencies table.

Fuel Purchase Obligations.  TVA has approximately $1.6 billion in long-term fuel purchase commitments ranging in terms of up to 6 years primarily for the purchase and transportation of coal.  TVA also has approximately $3.7 billion of long-term commitments ranging in terms of up to 16 years for the purchase of enriched uranium and fabrication of nuclear fuel assemblies.

Other Obligations.  Other obligations of $2.8 billion consist of contracts at September 30, 2014, for goods and services primarily related to capital projects as well as other major recurring operating costs.

Contingencies

Nuclear Insurance.  The Price-Anderson Act provides a layered framework of protection to compensate for losses arising from a nuclear event in the United States.  For the first layer, all of the NRC nuclear plant licensees, including TVA, purchase $375 million of nuclear liability insurance from American Nuclear Insurers for each plant with an operating license.  Funds for the second layer, the Secondary Financial Program, would come from an assessment of up to $127 million from the licensees of each of the 104 NRC licensed reactors in the United States.  The assessment for any nuclear accident would be limited to $19 million per year per unit.  American Nuclear Insurers, under a contract with the NRC, administers the Secondary Financial Program.  With its six licensed units, TVA could be required to pay a maximum of $764 million per nuclear incident, but it would have to pay no more than $114 million per incident in any one year.  When the contributions of the nuclear plant licensees are added to the insurance proceeds of $375 million, over $13.0 billion, including a five percent surcharge for legal expenses, would be available.  Under the Price-Anderson Act, if the first two layers are exhausted, the U.S. Congress is required to take action to provide additional funds to cover the additional losses.

TVA carries property, decommissioning, and decontamination insurance of $5.1 billion for its licensed nuclear plants, with up to $2.1 billion available for a loss at any one site, to cover the cost of stabilizing or shutting down a reactor after an accident.  Some of this insurance, which is purchased from Nuclear Electric Insurance Limited ("NEIL"), may require the payment of retrospective premiums up to a maximum of approximately $120 million.

TVA purchases accidental outage (business interruption) insurance for TVA’s nuclear sites from NEIL.  In the event that an accident covered by this policy takes a nuclear unit offline or keeps a nuclear unit offline, NEIL will pay TVA, after a waiting period, an indemnity (a set dollar amount per week) up to a maximum indemnity of $490 million per unit.  This insurance policy may require the payment of retrospective premiums up to a maximum of approximately $35 million.

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

Nuclear.  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, 2014, the present value of the estimated future decommissioning cost of $2.1 billion 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 the difference in the discount rates used to calculate the present value of decommissioning costs.

TVA maintains a NDT to provide funding for the ultimate decommissioning of its nuclear power plants.  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 will be available to support decommissioning.  TVA’s nuclear power units are currently authorized to operate until 2020-2036, 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 — Nuclear Decommissioning Costs and Note 12.

Non-Nuclear Decommissioning.  The present value of the estimated future non-nuclear decommissioning cost ARO was $1.1 billion at September 30, 2014.  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 power assets.  Estimates involved in determining if additional funding will be made to the ART include inflation rate and rate of return projections on the fund investments.  See Note 8 — Non-Nuclear Decommissioning Costs and Note 12.

Environmental Matters. TVA’s power generation activities, like those across the utility industry and in other industrial sectors, are subject to most federal, state, and local environmental laws and regulations.  Major areas of regulation affecting TVA’s activities include air quality control, water quality control, and management and disposal of solid and hazardous wastes.  In the future, regulations in all of these areas are expected to become more stringent.  Regulations are also expected to apply to new emissions and sources, with a particular emphasis on climate change, renewable generation, and energy efficiency.

TVA has incurred, and expects to continue to incur, substantial capital and operating and maintenance costs to comply with evolving environmental requirements primarily associated with, but not limited to, the operation of TVA’s coal-fired generating units.  It is virtually certain that environmental requirements placed on the operation of TVA’s coal-fired and other generating units will continue to become more restrictive and potentially apply to new emissions and sources.  Litigation over emissions or discharges from coal-fired generating units is also occurring, including litigation against TVA.  Failure to comply with environmental 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 the 1970s to 2014, TVA spent approximately $5.9 billion to reduce emissions from its power plants, including $378 million, $197 million, and $55 million in 2014, 2013, and 2012, respectively, on clean air controls.  TVA estimates that compliance with future Clean Air Act ("CAA") requirements (excluding greenhouse gas ("GHG") requirements) could lead to additional costs of $900 million from 2015 to 2025 for additional clean air controls.  There could be additional material costs if reductions of GHGs, including carbon dioxide, are mandated under the CAA or by legislation or regulation, or if future legislative, regulatory, or judicial actions lead to more stringent emission reduction requirements for conventional pollutants.  These costs cannot reasonably be predicted at this time because of the uncertainty of such potential actions.

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 is aware of alleged hazardous-substance releases at certain non-TVA areas in connection with which other potentially responsible parties may seek monetary damages from TVA.  There is information indicating that TVA sent a small amount of equipment to Ward Transformer (“Ward”), a non-TVA site in Raleigh, North Carolina.  The site is contaminated by PCBs from electrical equipment due to Ward’s practice of draining such equipment.  A working group of potentially responsible parties is cleaning up on-site contamination in accordance with an agreement with the EPA.  The cleanup effort has been divided into multiple phases, including on-site and downstream cleanup activities, two phases of soil cleanup, supplemental groundwater remediation, and cleanup of off-site contamination in the downstream drainage basin.  TVA settled its potential liability for the on-site removal action for $300 thousand and has agreed to pay approximately $8 thousand to settle its potential liability in connection with an EPA study of the site.  TVA believes that its liability for the remaining cleanup activities as well as any natural resource damages will be less than $1 million.

TVA operations at some TVA facilities have resulted in oil spills and other contamination that TVA is addressing.  At September 30, 2014 and 2013, TVA’s estimated liability for cleanup and similar environmental work for those sites for which sufficient information is available to develop a cost estimate (primarily the TVA sites) was approximately $15 million, on a non-discounted basis, and was included in Accounts payable and accrued liabilities and Other long-term liabilities on the Consolidated Balance Sheets.

Other. TVA is undertaking cost reduction initiatives with the goal of keeping rates low, keeping reliability high, and continuing to fulfill its broader mission of environmental stewardship and economic development. TVA’s current focus is on reducing operating and maintenance costs through further efficiency gains and streamlining the organization. The goal is to reduce TVA’s operating and maintenance costs by $500 million by 2015 as compared to its 2013 budget. As part of these cost reduction initiatives, an organizational restructuring occurred in 2014, which resulted in approximately 2,000 position reductions achieved through attrition, elimination of vacant positions, and employees leaving TVA either voluntarily or involuntarily. Certain employees were eligible for severance payments as a result of these cost reduction initiatives. As of September 30, 2014, TVA had $45 million accrued related to estimated future severance payments. See Note 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 a catastrophic event or otherwise.  

General. At September 30, 2014, TVA had accrued approximately $172 million of probable losses with respect to Legal Proceedings and estimated the range of these losses to be from $172 million to $173 million.  Of the accrued amount, $108 million is included in Other long-term liabilities and $64 million is included in Accounts payable and accrued liabilities.  TVA is currently unable to estimate any amount or any range of amounts of reasonably possible losses, and no assurance can be given that TVA will not be subject to significant additional claims and liabilities.  If actual liabilities significantly exceed the estimates made, TVA's results of operations, liquidity, and financial condition could be materially adversely affected.

Environmental Agreements. In April 2011, TVA entered into two substantively similar agreements, one with the EPA and the other with Alabama, Kentucky, North Carolina, Tennessee, and three environmental advocacy groups: the Sierra Club, the National Parks Conservation Association, and Our Children's Earth Foundation (collectively, the "Environmental Agreements”). They became effective in June 2011. Under the Environmental Agreements, TVA committed to (1) retire on a phased schedule 18 coal-fired units with a combined summer net dependable capability of 2,200 MW, (2) control, convert, or retire additional coal-fired units with a combined summer net dependable capability of 3,500 MW, (3) comply with annual, declining emission caps for SO₂ and NO_x, (4) invest $290 million in certain TVA environmental projects, (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 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, 2014 Consolidated Balance Sheet. In conjunction with the approval of the Environmental Agreements, the TVA Board determined that it was appropriate to record TVA's liabilities under the Environmental Agreements as regulatory assets, and they are included as such on the September 30, 2014 Consolidated Balance Sheet and will be recovered in rates in future periods.

Several legal and administrative clean air proceedings have already been terminated in connection with the Environmental Agreements. Additionally, the proceeding discussed below involving the John Sevier CAA permit is expected to be narrowed in scope or terminated since TVA has now retired all four of the John Sevier coal-fired units.

Legal Proceedings Related to the Kingston Ash Spill.  Seventy-eight lawsuits based on the Kingston ash spill were filed in the United States District Court for the Eastern District of Tennessee.  The plaintiffs - residents, businesses, and property owners in the Kingston area - sought unspecified compensatory and punitive damages for various tort claims, court orders to clean up properties, and other relief.  Fifteen of these lawsuits were dismissed prior to the third quarter of 2014.  On August 4, 2014, the court issued an agreed order that implements a mediated global resolution of pending claims.  Under the order, the 63 pending cases were dismissed with prejudice and TVA agreed to deposit $28 million with the court, which is responsible for disbursing the funds.  The order anticipates that further legal proceedings will be required to resolve the claims of nine of the plaintiffs, and a portion of the $28 million has been set aside under the order to cover the anticipated costs of resolving these claims.

Civil Penalty and Natural Resource Damages for the Kingston Ash Spill.  In June 2010, TDEC issued a civil penalty order of approximately $12 million to TVA for the Kingston ash spill, citing violations of the Tennessee Solid Waste Disposal Act and the Tennessee Water Quality Control Act.  Of the $12 million, TVA initially paid $10 million, and agreed to undertake environmental projects valued at $2 million as a credit against the remaining penalty amount. TVA completed several of those projects and has now decided to pay TDEC the remaining difference rather than do more projects. TVA has paid TDEC $750 thousand toward the remaining amount and still must pay another small amount.

Case Involving Tennessee Valley Authority Retirement System.  In March 2010, eight current and former participants in and beneficiaries of TVARS filed suit in the United States District Court for the Middle District of Tennessee against the six then-current members of the TVARS Board.  The lawsuit challenged the TVARS Board's decision to suspend the TVA contribution requirements for 2010 through 2013, and to amend the TVARS Rules and Regulations to (1) reduce the calculation for COLA benefits for CY 2010 through CY 2013, (2) reduce the interest crediting rate for the fixed fund accounts, and (3) increase the eligibility age to receive COLAs from age 55 to 60.  In September 2010, the district court dismissed this action, allowing the plaintiffs to file an amended complaint within 14 days against TVARS and TVA but not the individual directors, which the plaintiffs did shortly thereafter.  The plaintiffs allege, among other things, violations of their constitutional rights (due process, equal protection, and property rights), violations of the Administrative Procedure Act, and breach of statutory duties owed to the plaintiffs.  They seek a declaratory judgment and appropriate relief for the alleged statutory and constitutional violations and breaches of duty.  TVA filed its answer to the amended complaint in December 2010.  In May 2012, the court granted the parties' joint motion to administratively close the case subject to reopening to allow the parties the opportunity to engage in mediation. In July 2013, the court granted the plaintiffs' motion to reopen the lawsuit, and in November 2013, TVA filed a motion for summary judgment. The motion is still pending.

Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage. In June 2012, the U.S. Court of Appeals for the District of Columbia Circuit ("D.C. Circuit") vacated the NRC's updated WCD. The WCD is a generic determination by the NRC that spent nuclear fuel can be safely managed until a permanent off-site repository is established and has been a key component of the NRC licensing activities since 1984. The most recent update provided that the permanent repository would be available when necessary and that spent fuel could be stored for 60 years after a plant's license terminated. The D.C. Circuit vacated this update on the grounds that, among other things, the NRC failed to support it with an adequate National Environmental Policy Act review and the NRC did not evaluate what would happen if the repository was never built.

                In June 2012, multiple intervenor groups submitted a petition to the NRC to (1) hold in abeyance all pending reactor licensing decisions that would depend upon the WCD and (2) establish a process for ensuring that the remanded proceeding complies with the public participation requirements of Section 189a of the Atomic Energy Act.  In August 2012, the NRC issued an order (the "August 2012 NRC Order") preventing the issuance of a final licensing decision in all proceedings affected by the petition, including Watts Bar Unit 2, Sequoyah, and Bellefonte Units 3 and 4.  While resolution of unrelated contentions can proceed, the NRC stated that it will not issue final licensing decisions until it has “appropriately addressed” the D.C. Circuit decision, and all pending contentions concerning the WCD are being held in abeyance pending the NRC's completion of an environmental review and generic rulemaking addressing the shortcomings identified by the D.C. Circuit. In August 2014, the NRC issued a final rule and terminated its suspension of final licensing decisions, dismissed contentions related to the WCD pending before the NRC, and directed the Atomic Safety and Licensing Board ("ASLB") to dismiss contentions related to the WCD that were being held in abeyance.

The final rule on continued storage of spent nuclear fuel ("Continued Storage Rule") was published in the Federal Register in September 2014. Multiple intervenor groups submitted a petition to the NRC in multiple reactor licensing proceedings to suspend the issuance of final decisions in those proceedings until the NRC generically makes additional findings related to spent fuel disposal or those findings are made in individual licensing proceedings. In addition, in October 2014, attorneys general from New York, Connecticut, and Vermont filed a petition with the D.C. Circuit for review of the Continued Storage Rule. The petitioners asked the court to vacate the rule and related NRC actions and to remand the matter to the NRC for further analysis and the preparation and issuance of an environmental impact statement that complies with NEPA and other applicable laws and regulations.

Administrative Proceeding Regarding Renewal of Operating License for Sequoyah Nuclear Plant.  In May 2013, the Blue Ridge Environmental Defense League ("BREDL"), the Bellefonte Efficiency and Sustainability Team ("BEST"), and Mothers Against Tennessee River Radiation filed a petition with the NRC opposing the renewal of the operating license for Sequoyah Nuclear Plant Units 1 and 2. The petition contains eight specific contentions challenging the adequacy of the license renewal application that TVA submitted to the NRC in January 2013.  TVA filed a response with the ASLB opposing the admission of all eight of the petitioners' contentions. In July 2013, the ASLB concluded that BREDL is the only one of the three petitioners that has standing to intervene in this proceeding. The ASLB also held that seven of the contentions were inadmissible, and held one portion of the remaining contention related to WCD in abeyance pending further direction from the NRC. In September 2014, the ASLB denied BREDL's contention related to the WCD. Following the publication of the Continued Storage Rule, BREDL filed a petition with the NRC seeking suspension of the issuance of a final decision in the Sequoyah Nuclear Plant proceeding and a motion with the ASLB seeking leave to file a new, late-filed contention related to the Continued Storage Rule. See Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage.

Administrative Proceedings Regarding Bellefonte Units 3 and 4.  TVA submitted its combined construction and operating license application ("CCOLA") for two Advanced Passive 1000 reactors at Bellefonte Units 3 and 4 to the NRC in October 2007.  In June 2008, BEST, BREDL, and Southern Alliance for Clean Energy ("SACE") submitted a joint petition for intervention and a request for a hearing.  The ASLB denied standing to BEST and admitted four of the 20 contentions submitted by BREDL and SACE.  The NRC reversed the ASLB's decision to admit two of the four contentions, leaving only two contentions (concerning the estimated costs of the new nuclear plant and the impact of the facility's operations on aquatic ecology) to be litigated in a future hearing.  In January 2012, TVA notified the ASLB that the NRC had placed the CCOLA in “suspended” status indefinitely at TVA's request, and TVA requested that the ASLB hold the proceeding in abeyance pending a decision by TVA regarding the best path forward with regards to the CCOLA.

In July 2012, BREDL petitioned for the admission of another new, late-filed contention stemming from the D.C. Circuit's order vacating the WCD. In September 2014, the ASLB denied BREDL’s request to file the new contention. Following the publication of the Continued Storage Rule, BREDL filed a petition with the NRC seeking suspension of the issuance of a final decision in the Bellefonte Units 3 and 4 proceeding and a motion with the ASLB seeking leave to file a new, late-filed contention stemming from the Continued Storage Rule. See Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage.

Administrative Proceedings Regarding Watts Bar Unit 2.  In July 2009, SACE, the Tennessee Environmental Council, the Sierra Club, We the People, and BREDL filed a request for a hearing and petition to intervene in the NRC administrative process reviewing TVA's application for an operating license for Watts Bar Unit 2.  In November 2009, the ASLB granted SACE's request for hearing, admitted two of SACE's seven contentions for hearing, and denied the request for hearing submitted on behalf of the other four petitioners.  The ASLB subsequently dismissed one contention, leaving one aquatic impact contention.  In November 2011, TVA filed a motion for summary disposition, arguing that additional aquatic studies conducted by TVA indicate there is no longer a genuine issue of material fact in connection with SACE's remaining aquatic impact contention.  In July 2013, SACE filed a motion to withdraw its aquatic impact contention.  The ASLB has granted this motion.

In July 2012, SACE petitioned for the admission of another new, late-filed contention, similar to the one filed in the Bellefonte Units 3 and 4 proceeding, stemming from the D.C. Circuit's order vacating the WCD. In September 2014, the ASLB denied SACE’s request to file the contention related to the WCD and terminated the proceeding. Following the publication of the Continued Storage Rule, SACE filed a petition with the NRC seeking suspension of the issuance of a final decision in the Watts Bar Unit 2 proceeding and motions with the ASLB to reopen the record and for leave to file a new, late-filed contention stemming from the Continued Storage Rule. See Case Involving the NRC Waste Confidence Decision on Spent Nuclear Fuel Storage.

John Sevier Fossil Plant Clean Air Act Permit. In September 2010, the Environmental Integrity Project, the Southern Environmental Law Center, and the Tennessee Environmental Council filed a petition with the EPA, requesting that the EPA Administrator object to the CAA permit issued to TVA for operation of John Sevier. Among other things, the petitioners allege that repair, maintenance, or replacement activities undertaken at John Sevier Unit 3 in 1986 triggered the Prevention of Significant Deterioration ("PSD") requirements for SO₂ and NO_x. The CAA permit, issued by TDEC, remains in effect pending the disposition of the petition. The Environmental Agreements should narrow the scope of this proceeding. See Environmental Agreements. TVA has now retired all four John Sevier coal-fired units, and this challenge likely will not proceed.

National Environmental Policy Act Challenge at Gallatin Fossil Plant. To comply with the Environmental Agreements and the Mercury and Air Toxics Standards, TVA chose to reduce emissions at the Gallatin Fossil Plant by installing controls and an associated landfill. Pursuant to the National Environmental Policy Act ("NEPA"), TVA completed an Environmental Assessment in March 2013 to assess the impact of installing these emission controls. In April 2013, the Tennessee Environmental Council, Tennessee Scenic Rivers Association, Sierra Club, and Center for Biological Diversity filed suit in the United States District Court for the Middle District of Tennessee alleging that TVA violated NEPA when it decided to install additional emission controls and construct an associated landfill at the Gallatin Fossil Plant. Plaintiffs demand that TVA prepare an Environmental Impact Statement, and are asking the court to enjoin TVA from taking any further action relating to these matters pending compliance with NEPA. This case was transferred to the United States District Court for the Eastern District of Tennessee, and in August 2014, the court granted TVA's motion for summary judgment and dismissed all of the plaintiffs' claims. The plaintiffs did not appeal the district court’s judgment by the appeal deadline of September 30, 2014.

National Environmental Policy Act Challenge at Paradise Fossil Plant. To comply with EPA’s Mercury and Air Toxics Standards, TVA chose to retire two coal-fired units at Paradise Fossil Plant and replace them with natural gas generation. Prior to making this decision, TVA completed an Environmental Assessment in November 2013 under NEPA. In July 2014, the Kentucky Coal Association and several individuals filed suit in the United States District Court for the Western District of Kentucky alleging that TVA violated NEPA and the Energy Policy Act of 1992 in deciding to switch to natural gas generation. The plaintiffs demand that TVA prepare an Environmental Impact Statement, and are asking the court to preliminarily enjoin TVA from taking any further action relating to these matters pending compliance with NEPA. TVA has filed an opposition to the plaintiffs’ motion for a preliminary injunction as well as a motion for judgment on the administrative record. A hearing on the preliminary injunction motion is scheduled in November 2014, and briefing on TVA’s motion for judgment is ongoing.

Kingston Fossil Plant NPDES Permit Administrative Appeal.  The Sierra Club filed a challenge to the National Pollutant Discharge Elimination System ("NPDES") permit issued by Tennessee for the scrubber-gypsum pond discharge at Kingston in November 2009 before the Tennessee Board of Water Quality, Oil, and Gas ("TN Board").  TDEC is the defendant in the challenge, and TVA has intervened in support of TDEC's decision to issue the permit.  At the request of the parties, the Administrative Law Judge ("ALJ") assigned to the matter has stayed the case until October 15, 2015.  

Bull Run Fossil Plant NPDES Permit Administrative Appeal.  SACE and the Tennessee Clean Water Network ("TCWN") filed a challenge to the NPDES permit for the Bull Run Fossil Plant in November 2010.  TDEC is the defendant in the challenge, and TVA's motion to intervene to support TDEC's decision to issue the permit was granted in January 2011.  At the contested case hearing in October 2013, the TN Board granted TDEC's and TVA's joint motion for involuntary dismissal following the conclusion of the petitioners' presentation of evidence. On December 18, 2013, TCWN and SACE filed a petition for review of the TN Board's decision in the Chancery Court for Davidson, County, Tennessee. The parties have filed appellate briefs, and oral argument is set to be heard on January 27, 2015.

Johnsonville Fossil Plant NPDES Permit Administrative Appeal.  SACE and TCWN filed a challenge to the NPDES permit for the Johnsonville Fossil Plant in March 2011.  TDEC is the defendant in the challenge.  TVA's motion to intervene was granted in August 2011. The matter has not yet been given a hearing date before the TN Board.

John Sevier Fossil Plant NPDES Permit Administrative Appeal.  SACE and TCWN filed a challenge to the NPDES permit for John Sevier in May 2011.  TDEC is the defendant in the challenge.  TVA's motion to intervene was granted in August 2011. The matter has not yet been given a hearing date before the TN Board.

Gallatin Fossil Plant NPDES Permit Administrative Appeal. SACE, TCWN, and the Sierra Club filed a challenge to the NPDES permit for the Gallatin Fossil Plant in June 2012. TDEC is the defendant in the challenge. TVA's motion to intervene was granted in September 2012. Following discovery, SACE, TCWN, and the Sierra Club voluntarily dismissed seven of the eight claims asserted in their petition. TVA moved to dismiss the remaining claim, and the ALJ assigned to the matter granted TVA’s motion and dismissed the case. On November 7, 2014, SACE, TWCN, and the Sierra Club filed a petition for review of the ALJ's dismissal in the Chancery court for Davidson County, Tennessee.

Petitions Resulting from Japanese Nuclear Events. As a result of events that occurred at the Fukushima Daiichi Nuclear Power Plant in March 2011, petitions have been filed with the NRC which could impact TVA's nuclear program. While some petitions have been dismissed after review, petitions that remain open include the following:

• Petition to Immediately Suspend the Operating Licenses of GE BWR Mark I Units Pending the Full NRC Review With Independent Expert and Public Participation From Affected Emergency Planning Zone Communities

Beyond Nuclear filed a petition in April 2011, requesting that the NRC take emergency enforcement action against all nuclear reactor licensees that operate units that use the General Electric Mark I BWR design. TVA uses this design at Browns Ferry Units 1, 2, and 3. The petition requests the NRC to take several actions, including the suspension of the operating licenses at the affected nuclear units, including Browns Ferry, until several milestones have been met. In December 2011, the NRC provided its initial response to the petition. The NRC accepted five specific requests that would apply directly or indirectly to Browns Ferry, including issues relating to spent fuel pool use and location, Mark I containment hardened vent systems and design, and backup electrical power. Each of these items was accepted for further investigation, but the requests for immediate action were rejected. The NRC has not yet rendered a decision regarding the petition.

• Twelve separate petitions on various issues

In August 2011, the Natural Resources Defense Council submitted twelve separate letters to the NRC requesting action on various health and safety aspects of operating nuclear facilities in the United States. The NRC is treating these as a single 10 CFR 2.206 Petition. The NRC closed this petition on June 17, 2014.

• Petition Pursuant to 10 CFR 2.206 - Demand For Information Regarding Compliance with 10 CFR 50, Appendix A, General Design Criterion 44, Cooling Water, and 10 CFR 50.49, Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants.

A petition was filed by the Union of Concerned Scientists in July 2011, requesting that a demand for information be issued for affected licensees, including TVA with regards to Browns Ferry, describing how the facilities comply with General Design Criterion 44, Cooling Water, within Appendix A to 10 CFR Part 50, and with 10 CFR 50.49, Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants, for all applicable design and licensing bases events. The NRC has not yet rendered a decision regarding the petition.

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Commitments and Contingencies Commitments and Contingencies - Purchase Obligations (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014 Facilities Hours Megawatts	Sep. 30, 2013	Sep. 30, 2012	Aug. 09, 2013
Obligations
Membership interests of VIE subject to mandatory redemption	$ 50	$ 50		$ 40
Megawatts provided under power purchase obligations	1,621
Remaining terms of the agreements, high end of range	18 years
Power purchased under agreement	293	322	447
Number of U.S. Army Corps of Engineers hydroelectric facilities contracted with to obtain power	8
Agreement termination notice period	3 years
Minimum required hours of power	1,500
Megawatt allocation	405
Maximum term length for the purchase and transportation of coal	6 years
Maximum term for purchase of enriched uranium and fabrication of nuclear fuel assemblies	16 years
Purchase Agreements Required by Federal Law
Obligations
Megawatts provided under power purchase obligations	890
Number of suppliers	6
Purchase Obligations - Coal
Obligations
Long-term purchase commitment	1,600
Purchase Obligations - Nuclear Fuel
Obligations
Long-term purchase commitment	3,700
Purchase Obligations - Other
Obligations
Long-term purchase commitment	$ 2,752

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Debt and Other Obligations Debt and Other Obligations - Debt Securities Activity (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Debt Instrument
Issues of variable interest entities	$ 0		$ 360		$ 1,000
Issues of power bonds	989		2,122		1,126
Amount	395		2,371
Redemptions/Maturities of variable interest entities	30		13		6
Redemptions/Maturities of power bonds	365		2,358		2,717
Discount on debt issues	(11)		(30)
Debt of variable interest entities
Debt Instrument
Redemptions/Maturities of variable interest entities	30	[1]	13	[1]
Electronotes
Debt Instrument
Redemptions/Maturities of power bonds	335	[1]	50	[1]
1998 Series C
Debt Instrument
Redemptions/Maturities of power bonds	0	[1]	1,359	[1]
1998 Series D
Debt Instrument
Redemptions/Maturities of power bonds	0	[1]	2	[1]
1999 Series A
Debt Instrument
Redemptions/Maturities of power bonds	0	[1]	1	[1]
2003 Series C
Debt Instrument
Redemptions/Maturities of power bonds	0	[1]	940	[1]
2009 Series A
Debt Instrument
Redemptions/Maturities of power bonds	4	[1]	4	[1]
2009 Series B
Debt Instrument
Redemptions/Maturities of power bonds	26	[1]	2	[1]
2013 Series A
Debt Instrument
Percent of par value			99.52%
2014 Series A
Debt Instrument
Percent of par value	98.94%
Total
Debt Instrument
Percent of par value	100.00%
Debt of variable interest entities
Debt Instrument
Issues of variable interest entities	0		360
Electronotes
Debt Instrument
Issues of power bonds	0		152
2012 Series B
Debt Instrument
Issues of power bonds	0		1,000	[2]
Percent of par value			97.49%
2013 Series A
Debt Instrument
Issues of power bonds	0		1,000	[3]
2014 Series A
Debt Instrument
Issues of power bonds	1,000	[4]	0
Total
Debt Instrument
Amount	$ 989		$ 2,482

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

[2] The 2012 Series B bonds were issued at 97.49 percent of par.

[3] The 2013 Series A bonds were issued at 99.52 percent of par.

[4] The 2014 Series A bonds were issued at 98.94 percent of par.

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Inventories, Net Inventories, Net (Tables)

12 Months Ended

Sep. 30, 2014

Inventory, Net [Abstract]

Inventories, Net

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

Inventories, Net At September 30
	2014			2013
Materials and supplies inventory	$	616		$	620
Fuel inventory	473			494
Emission allowance inventory	13			14
Allowance for inventory obsolescence	(46		)	(37		)
Inventories, net	$	1,056		$	1,091

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Accumulated Other Comprehensive Income (Loss)

12 Months Ended

Sep. 30, 2014

Equity [Abstract]

Disclosure of Reclassification Amount [Text Block]

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 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 year-ended September 30, 2014, TVA reclassified $2 million of gains related to its cash flow hedges from AOCI to Interest expense. See Note 15.

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 7, Note 15 — Overview of Accounting Treatment, Note 16, and Note 20.

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Benefit Plans Projected Benefit Obligations and Accumulated Benefit Obligations in Exess of Plan Assets (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Defined Benefit Plan Disclosure
Projected benefit obligation	$ 12,265	$ 11,471
Accumulated benefit obligation	12,039	11,216
Fair value of net plan assets	$ 7,507	$ 7,221