Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(MARK ONE)

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

SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~March 31,~~June 30, 2013

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)

None

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

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 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. (Check one):

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 Exchange Act).

Yes o No x

Table of Contents

~~Table of Contents~~



Table of Contents


GLOSSARY OF COMMON ACRONYMS......................................................................................................................................	43
FORWARD-LOOKING INFORMATION.........................................................................................................................................	65
GENERAL INFORMATION............................................................................................................................................................	76

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS.............................................................................................................................................	87
Consolidated Statements of Operations (unaudited)............................................................................................................	87
Consolidated Statements of Comprehensive Income (Loss) (unaudited).............................................................................	87
Consolidated Balance Sheets (unaudited)............................................................................................................................	98
Consolidated Statements of Cash Flows (unaudited)...........................................................................................................	1110
Consolidated Statements of Changes in Proprietary Capital (unaudited).............................................................................	1211
Notes to Consolidated Financial Statements (unaudited).....................................................................................................	1312

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS...	4039
Executive Overview...............................................................................................................................................................	4039
Results of Operations............................................................................................................................................................	40
Liquidity and Capital Resources............................................................................................................................................	4544
2013 Key Initiatives and Challenges.....................................................................................................................................	5150
Environmental Matters..........................................................................................................................................................	53
Legal Proceedings................................................................................................................................................................	54
Off-Balance Sheet Arrangements.........................................................................................................................................	54
Critical Accounting Policies and Estimates...........................................................................................................................	54
New Accounting Standards and Interpretations....................................................................................................................	54
Corporate Governance..........................................................................................................................................................	54
Other Matters........................................................................................................................................................................	55

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK..............................................................	55

ITEM 4. CONTROLS AND PROCEDURES..................................................................................................................................	55
Disclosure Controls and Procedures......................................................................................................................................	55
Changes in Internal Control over Financial Reporting............................................................................................................	55

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS..................................................................................................................................................	56

ITEM 1A. RISK FACTORS...........................................................................................................................................................	56

ITEM 6. EXHIBITS.......................................................................................................................................................................	57

SIGNATURES...............................................................................................................................................................................	58

EXHIBIT INDEX............................................................................................................................................................................	59

Table of Contents



GLOSSARY OF COMMON ACRONYMS
Following are definitions of terms or acronyms frequently used in this Quarterly Report on Form 10-Q for the quarter ended ~~March 31,~~June 30, 2013 (the “Quarterly 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
CME		Chicago Mercantile Exchange
CO₂		Carbon dioxide
COLA		Cost of living adjustment
CSAPR		Cross State Air Pollution Rule
CTs		Combustion turbine unit(s)
CVA		Credit valuation adjustment
CY		Calendar year
DOE		Department of Energy
EPA		Environmental Protection Agency
FASB		Financial Accounting Standards Board
FERC		Federal Energy Regulatory Commission
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)
JSCCG		John Sevier Combined Cycle Generation LLC
kWh		Kilowatt hour(s)
LIBOR		London Interbank ~~Offer~~Offered Rate
MD&A		Management’s Discussion and Analysis of Financial Condition and Results of Operations
MISO		~~Midwest~~Midcontinent Independent Transmission System Operator, Inc.
mmBtu		Million British thermal unit(s)
MtM		Mark-to-market
MW		Megawatt
NAV		Net asset value
NDT		Nuclear Decommissioning Trust
NEPA		National Environmental Policy Act
NERC		North American Electric Reliability Corporation
NO_x		Nitrogen oxides
NPDES		National Pollutant Discharge Elimination System
NRC		Nuclear Regulatory Commission
~~NSPS~~		~~New Source Performance Standards~~
OCI		Other Comprehensive Income (Loss)
PM		Particulate matter
QTE		Qualified technological equipment and software

Table of Contents



~~QTE~~		~~Qualified technological equipment and software~~
REIT		Real Estate Investment Trust
SACE		Southern Alliance for Clean Energy
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
TN Board		Tennessee Water Quality, Oil, and Gas Board
USEC		United States Enrichment Corporation
VIE		Variable interest entity
XBRL		eXtensible Business Reporting Language

Table of Contents

FORWARD-LOOKING INFORMATION

This Quarterly Report contains forward-looking statements relating to future events and future performance. All statements other than those that are purely historical may be forward-looking statements. In certain cases, forward-looking statements can be identified by the use of words such as “may,” “will,” “should,” “expect,” “anticipate,” “believe,” “intend,” “project,” “plan,” “predict,” “assume,” “forecast,” “estimate,” “objective,” “possible,” “probably,” “likely,” “potential,” "speculate," 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 changed laws, regulations, and administrative orders, including those related to environmental matters, and the costs of complying with these new or changed laws, regulations, and administrative orders, as well as complying with existing laws, regulations, and administrative orders;

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");

Events at a TVA nuclear 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 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, 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 Bellefonte Nuclear Plant ("Bellefonte") Unit 1, or cause TVA to forego future construction at these or other facilities;

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

Settlements, natural resource damages, fines and penalties associated with the Kingston Fossil Plant ("Kingston") ash spill;

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

The outcome of legal and administrative proceedings;

Significant changes in demand for electricity;

Addition or loss of customers;

The continued operation, performance, or failure of TVA's generation, transmission, flood control, and related assets, including coal combustion residual ("CCR") facilities;

The cost of complying with existing and anticipated emissions reduction requirements, 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;

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 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, as well as inadequacies in the supply of water to TVA's generation facilities;

Inability to obtain regulatory approval for the construction or operation of assets;

Weather conditions;

Catastrophic events such as fires, earthquakes, solar events, 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;

Restrictions on TVA's ability to use or manage real property currently under its control;

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;

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

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

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

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

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 TVA Act of 1933;

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;

Actions taken by the U.S. government to address the situation of approaching its debt limit;

Changes in the economy and volatility in financial markets;

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

Table of Contents

Problems attracting and retaining a qualified workforce;

Changes in technology;

~~Table of Contents~~

Failure of TVA's assets to operate as planned;

Failure of TVA's cyber security program to protect TVA's assets from cyber attacks;

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

Unforeseeable events.

See also Item 1A, Risk Factors, and Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations in TVA’s Annual Report on Form 10-K for the fiscal year ended September 30, 2012 (the “Annual Report”) and Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations in this Quarterly Report. 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 (2013, 2012, etc.) in this Quarterly Report are to TVA’s fiscal years ending September 30. Years that are preceded by “CY” are references to calendar years.

Notes

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

Available Information

TVA'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 Quarterly 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.

Table of Contents

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(in millions)


	Three Months Ended March 31						Six Months Ended March 31						Three Months Ended June 30						Nine Months Ended June 30
	2013			2012			2013			2012			2013			2012			2013			2012
Operating revenues
Sales of electricity	$	2,709		$	2,569		$	5,258		$	5,109		$	2,572		$	2,741		$	7,830		$	7,850
Other revenue	32			35			62			63			30			36			92			99
Total operating revenues	2,741			2,604			5,320			5,172			2,602			2,777			7,922			7,949
Operating expenses
Fuel	672			524			1,466			1,164			652			683			2,118			1,847
Purchased power	288			329			533			648			263			277			796			925
Operating and maintenance	876			863			1,795			1,743			866			882			2,662			2,625
Depreciation and amortization	408			493			836			934			412			505			1,248			1,439
Tax equivalents	136			149			273			300			131			152			404			452
Total operating expenses	2,380			2,358			4,903			4,789			2,324			2,499			7,228			7,288
Operating income	361			246			417			383			278			278			694			661
Other income (expense), net	11			(14		)	26			(5		)	10			21			36			16
Interest expense
Interest expense	359			368			714			726			343			366			1,057			1,092
Allowance for funds used during construction and nuclear fuel expenditures	(41		)	(42		)	(80		)	(81		)	(43		)	(44		)	(124		)	(125		)
Net interest expense	318			326			634			645			300			322			933			967
Net income (loss)	$	54		$	(94	)	$	(191	)	$	(267	)	$	(12	)	$	(23	)	$	(203	)	$	(290	)
The accompanying notes are an integral part of these consolidated financial statements.

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited)

(in millions)


	Three Months Ended March 31						Six Months Ended March 31						Three Months Ended June 30						Nine Months Ended June 30
	2013			2012			2013			2012			2013			2012			2013			2012

Net income (loss)	$	54		$	(94	)	$	(191	)	$	(267	)	$	(12	)	$	(23	)	$	(203	)	$	(290	)
Other comprehensive income (loss)
Net unrealized gain (loss) on cash flow hedges	(49		)	21			(16		)	64			9			(36		)	(7		)	27
Reclassification to earnings from cash flow hedges	63			(28		)	58			(26		)	(1		)	18			57			(7		)
Total other comprehensive income (loss)	$	14		$	(7	)	$	42		$	38		$	8		$	(18	)	$	50		$	20
Total comprehensive income (loss)	$	68		$	(101	)	$	(149	)	$	(229	)	$	(4	)	$	(41	)	$	(153	)	$	(270	)
The accompanying notes are an integral part of these consolidated financial statements.

Table of Contents

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED BALANCE SHEETS

(in millions)

													ASSETS
	March 31, 2013			September 30, 2012			June 30, 2013			September 30, 2012
Current assets	(Unaudited)						(Unaudited)
Cash and cash equivalents	$	919		$	868		$	980		$	868
Restricted cash and investments	—			11			—			11
Accounts receivable, net	1,361			1,666			1,492			1,666
Inventories, net	1,178			1,097			1,164			1,097
Regulatory assets	584			774			559			774
Other current assets	77			90			72			90
Total current assets	4,119			4,506			4,267			4,506

Property, plant, and equipment
Completed plant	46,475			45,917			46,790			45,917
Less accumulated depreciation	(22,632		)	(22,169		)	(22,942		)	(22,169		)
Net completed plant	23,843			23,748			23,848			23,748
Construction in progress	4,893			4,768			5,149			4,768
Nuclear fuel	1,280			1,176			1,239			1,176
Capital leases	31			35			42			35
Total property, plant, and equipment, net	30,047			29,727			30,278			29,727

Investment funds	1,569			1,465			1,570			1,465

Regulatory and other long-term assets
Regulatory assets	10,352			11,127			9,945			11,127
Other long-term assets	405			509			420			509
Total regulatory and other long-term assets	10,757			11,636			10,365			11,636

Total assets	$	46,492		$	47,334		$	46,480		$	47,334
The accompanying notes are an integral part of these consolidated financial statements.

Table of Contents

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED BALANCE SHEETS

(in millions)

													LIABILITIES AND PROPRIETARY CAPITAL
	March 31, 2013			September 30, 2012			June 30, 2013			September 30, 2012
Current liabilities	(Unaudited)						(Unaudited)
Accounts payable and accrued liabilities	$	1,678		$	1,922		$	1,580		$	1,922
Environmental cleanup costs - Kingston ash spill	126			126			110			126
Accrued interest	398			376			324			376
Current portion of leaseback obligations	438			443			434			443
Current portion of energy prepayment obligations	100			102			100			102
Regulatory liabilities	188			191			208			191
Short-term debt, net	2,045			1,507			2,395			1,507
Current maturities of power bonds	1,242			2,308			972			2,308
Current maturities of long-term debt of variable interest entities	13			13			13			13
Total current liabilities	6,228			6,988			6,136			6,988

Other liabilities
Post-retirement and post-employment benefit obligations	6,349			6,279			6,421			6,279
Asset retirement obligations	3,324			3,289			3,404			3,289
Other long-term liabilities	2,227			2,680			1,967			2,680
Leaseback obligations	712			760			693			760
Energy prepayment obligations	460			510			435			510
Environmental cleanup costs - Kingston ash spill	91			143			77			143
Regulatory liabilities	3			109			4			109
Total other liabilities	13,166			13,770			13,001			13,770

Long-term debt, net
Long-term power bonds, net	20,959			20,269			21,214			20,269
Long-term debt of variable interest entities	975			981			975			981
Total long-term debt, net	21,934			21,250			22,189			21,250

Total liabilities	41,328			42,008			41,326			42,008

Proprietary capital
Power program appropriation investment	278			288			273			288
Power program retained earnings	4,302			4,492			4,292			4,492
Total power program proprietary capital	4,580			4,780			4,565			4,780
Nonpower programs appropriation investment, net	616			620			613			620
Accumulated other comprehensive income (loss)	(32		)	(74		)	(24		)	(74		)
Total proprietary capital	5,164			5,326			5,154			5,326

Total liabilities and proprietary capital	$	46,492		$	47,334		$	46,480		$	47,334
The accompanying notes are an integral part of these consolidated financial statements.

109

Table of Contents

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

For the ~~six~~nine months ended ~~March 31~~June 30

(in millions)


	2013			2012			2013			2012
Cash flows from operating activities
Net income (loss)	$	(191	)	$	(267	)	$	(203	)	$	(290	)
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)	857			945			1,280			1,457
Amortization of nuclear fuel cost	117			130			186			195
Non-cash retirement benefit expense	311			304			467			456
Prepayment credits applied to revenue	(52		)	(53		)	(77		)	(79		)
Fuel cost adjustment deferral	55			54			93			(12		)
Fuel cost tax equivalents	3			16			2			28
Environmental cleanup costs – Kingston ash spill – non cash	36			36			54			55
Changes in current assets and liabilities
Accounts receivable, net	312			472			169			103
Inventories and other, net	(54		)	(421		)	(58		)	(335		)
Accounts payable and accrued liabilities	(171		)	(266		)	(258		)	(137		)
Accrued interest	22			25			(52		)	(63		)
Environmental cleanup costs – Kingston ash spill, net	(51		)	(58		)	(76		)	(81		)
Other, net	(46		)	(50		)	(49		)	(45		)
Net cash provided by operating activities	1,148			867			1,478			1,252
Cash flows from investing activities
Construction expenditures	(996		)	(1,143		)	(1,510		)	(1,617		)
Nuclear fuel expenditures	(213		)	(225		)	(238		)	(264		)
Loans and other receivables
Advances	(4		)	(2		)	(4		)	(2		)
Repayments	5			5			7			9
Other, net	4			6			—			7
Net cash used in investing activities	(1,204		)	(1,359		)	(1,745		)	(1,867		)
Cash flows from financing activities
Long-term debt
Issues of power bonds	1,067			69			1,080			135
Issues of variable interest entities	—			1,000			—			1,000
Redemptions and repurchases of power bonds	(1,387		)	(125		)	(1,417		)	(2,690		)
Redemptions of variable interest entities	(6		)	—			(6		)	—
Short-term debt issues (redemptions), net	537			(482		)	887			2,047
Payments on leases and leasebacks	(55		)	(52		)	(78		)	(75		)
Proceeds from call monetization							—			60
Financing costs, net	(7		)	(10		)	(7		)	(72		)
Change in restricted cash of variable interest entity	—			(30		)	—			(30		)
Payments to U.S. Treasury	(13		)	(13		)	(19		)	(21		)
Other, net	(29		)	(1		)	(61		)	1
Net cash provided by financing activities	107			356			379			355
Net change in cash and cash equivalents	51			(136		)	112			(260		)
Cash and cash equivalents at beginning of period	868			507			868			507
Cash and cash equivalents at end of period	$	919		$	371		$	980		$	247
The accompanying notes are an integral part of these consolidated financial statements.

1110

Table of Contents

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL (Unaudited)

For the three months ended ~~March 31,~~June 30, 2013, and 2012

(in millions)


	Power Program Appropriation Investment			Power Program Retained Earnings			Nonpower Programs Appropriation Investment, Net			Accumulated Other Comprehensive Income (Loss)			Total			Power Program Appropriation Investment			Power Program Retained Earnings			Nonpower Programs Appropriation Investment, Net			Accumulated Other Comprehensive Income (Loss)			Total
Balance at December 31, 2011 (unaudited)	$	303		$	4,257		$	627		$	(93	)	$	5,094
Balance at March 31, 2012 (unaudited)																$	298		$	4,164		$	625		$	(100	)	$	4,987
Net income (loss)	—			(92		)	(2		)	—			(94		)	—			(20		)	(3		)	—			(23		)
Total other comprehensive income (loss)	—			—			—			(7		)	(7		)	—			—			—			(18		)	(18		)
Return on power program appropriation investment	—			(1		)	—			—			(1		)	—			(3		)	—			—			(3		)
Return of power program appropriation investment	(5		)	$	—		—			—			(5		)	(5		)	$	—		—			—			(5		)
Balance at March 31, 2012 (unaudited)	$	298		$	4,164		$	625		$	(100	)	$	4,987
Balance at June 30, 2012 (unaudited)																$	293		$	4,141		$	622		$	(118	)	$	4,938

Balance at December 31, 2012 (unaudited)	$	283		$	4,249		$	617		$	(46	)	$	5,103
Balance at March 31, 2013 (unaudited)																$	278		$	4,302		$	616		$	(32	)	$	5,164
Net income (loss)	—			55			(1		)	—			54			—			(9		)	(3		)	—			(12		)
Total other comprehensive income (loss)	—			—			—			14			14			—			—			—			8			8
Return on power program appropriation investment	—			(2		)	—			—			(2		)	—			(1		)	—			—			(1		)
Return of power program appropriation investment	(5		)	—			—			—			(5		)	(5		)	—			—			—			(5		)
Balance at March 31, 2013 (unaudited)	$	278		$	4,302		$	616		$	(32	)	$	5,164
Balance at June 30, 2013 (unaudited)																$	273		$	4,292		$	613		$	(24	)	$	5,154
The accompanying notes are an integral part of these consolidated financial statements.

TENNESSEE VALLEY AUTHORITY

CONSOLIDATED STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL (Unaudited)

For the ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012

(in millions)


	Power Program Appropriation Investment			Power Program Retained Earnings			Nonpower Programs Appropriation Investment, Net			Accumulated Other Comprehensive Income (Loss)			Total			Power Program Appropriation Investment			Power Program Retained Earnings			Nonpower Programs Appropriation Investment, Net			Accumulated Other Comprehensive Income (Loss)			Total
Balance at September 30, 2011	$	308		$	4,429		$	630		$	(138	)	$	5,229		$	308		$	4,429		$	630		$	(138	)	$	5,229
Net income (loss)	—			(262		)	(5		)	—			(267		)	—			(282		)	(8		)	—			(290		)
Total other comprehensive income (loss)	—			—			—			38			38			—			—			—			20			20
Return on power program appropriation investment	—			(3		)	—			—			(3		)	—			(6		)	—			—			(6		)
Return of power program appropriation investment	(10		)	$	—		—			—			(10		)	(15		)	$	—		—			—			(15		)
Balance at March 31, 2012 (unaudited)	$	298		$	4,164		$	625		$	(100	)	$	4,987
Balance at June 30, 2012 (unaudited)																$	293		$	4,141		$	622		$	(118	)	$	4,938

Balance at September 30, 2012	$	288		$	4,492		$	620		$	(74	)	$	5,326		$	288		$	4,492		$	620		$	(74	)	$	5,326
Net income (loss)	—			(187		)	(4		)	—			(191		)	—			(196		)	(7		)	—			(203		)
Total other comprehensive income (loss)	—			—			—			42			42			—			—			—			50			50
Return on power program appropriation investment	—			(3		)	—			—			(3		)	—			(4		)	—			—			(4		)
Return of power program appropriation investment	(10		)	—			—			—			(10		)	(15		)	—			—			—			(15		)
Balance at March 31, 2013 (unaudited)	$	278		$	4,302		$	616		$	(32	)	$	5,164
Balance at June 30, 2013 (unaudited)																$	273		$	4,292		$	613		$	(24	)	$	5,154
The accompanying notes are an integral part of these consolidated financial statements.

1211

Table of Contents

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

(Dollars in millions except where noted)


Note No.	Note No.		Page No.	Note No.		Page No.
1		Summary of Significant Accounting Policies	13		Summary of Significant Accounting Policies	12
2		Impact of New Accounting Standards and Interpretations	15		Impact of New Accounting Standards and Interpretations	14
3		Accounts Receivable, Net	16		Accounts Receivable, Net	15
4		Inventories, Net	16		Inventories, Net	15
5		Other Long-Term Assets	16		Other Long-Term Assets	15
6		Regulatory Assets and Liabilities	17		Regulatory Assets and Liabilities	16
7		Variable Interest Entities	17		Variable Interest Entities	16
8		Kingston Fossil Plant Ash Spill	18		Kingston Fossil Plant Ash Spill	17
9		Other Long-Term Liabilities	19		Other Long-Term Liabilities	18
10		Asset Retirement Obligations	20		Asset Retirement Obligations	19
11		Debt and Other Obligations	20		Debt and Other Obligations	19
12		Lease/Leaseback Obligations	21		Lease/Leaseback Obligations	20
13		Risk Management Activities and Derivative Transactions	22		Risk Management Activities and Derivative Transactions	21
14		Fair Value Measurements	28		Fair Value Measurements	27
15		Other Income (Expense), Net	35		Other Income (Expense), Net	34
16		Benefit Plans	35		Benefit Plans	34
17		Legal Proceedings	35		Legal Proceedings	34
18		Subsequent Events	39

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 to provide recreational opportunities, adequate water supply, improved water quality, 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 in repayment of and as a return on the government's appropriation investment in TVA's power facilities (the "Power Program Appropriation Investment"). In the 1998 Energy and Water Development Appropriations Act, Congress directed TVA to fund essential stewardship activities related to its management of the Tennessee River system and nonpower or stewardship properties with power revenues in the event that there were insufficient appropriations or other available funds to pay for such activities in any fiscal year. Congress has not provided any appropriations to TVA to fund such activities since 1999. Consequently, during 2000, TVA began paying for essential stewardship activities primarily with power revenues, with the remainder funded with user fees and other forms of revenues derived in connection with those activities. The activities related to stewardship properties do not meet the criteria of an operating segment under accounting principles generally accepted in the United States of America ("GAAP"). Accordingly, these assets and properties are included as part of the power program, TVA's only operating segment.

Power rates are established by the TVA Board of Directors (the "TVA Board") as authorized by the Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (as amended, the “TVA Act”). The TVA Act requires TVA to charge

~~Table of Contents~~

rates for power that will produce gross revenues sufficient to provide funds for operation, maintenance, and administration of its

Table of Contents

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 (2013, 2012, 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 of providing electricity. 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 deferrals 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. In the event that accounting rules for rate regulation were no longer applicable, TVA would be required to write off its regulatory assets and liabilities, resulting in ~~charges~~changes to net income and other comprehensive income.

Basis of Presentation

TVA prepares its consolidated interim financial statements in conformity with GAAP for consolidated interim financial information. Accordingly, TVA's consolidated interim financial statements do not include all of the information and notes required by GAAP for annual financial statements. As such, they should be read in conjunction with the audited financial statements for the year ended September 30, 2012, and the notes thereto, which are contained in TVA's Annual Report on Form 10-K for the year ended September 30, 2012 (the “Annual Report”). In the opinion of management, all adjustments (consisting of items of a normal recurring nature) considered necessary for fair presentation are included in the interim financial statements.

The accompanying consolidated interim financial statements include the accounts of TVA and two variable interest entities ("VIEs"), created in January 2012, of which TVA is the primary beneficiary. See Note 7. 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 deemed critical either when a different estimate could have reasonably been used or where changes in the estimate are reasonably likely to occur from period to period and such use or change would materially impact TVA's financial condition, results of operations, or cash flows.

Reclassifications

Certain reclassifications have been made to the 2012 financial statements to conform to the 2013 presentation. In the Cash flows from operating activities section of the Consolidated Statements of Cash Flows, $67119 million previously reported as changes in Other, net and $~~(323)~~(318) million previously reported as changes in Margin cash collateral, net for the ~~six~~nine months ended ~~March 31,~~June 30, 2012, were reclassified as changes in Inventory and other, net.

~~Table of Contents~~

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

Table of Contents

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 $4 million and $7 million at ~~March 31,~~June 30, 2013 and September 30, 2012, respectively, for accounts receivable. Additionally, loans receivable of $7984 million and $76 million at ~~March 31,~~June 30, 2013 and September 30, 2012, respectively, are included in Other long-term assets and reported net of allowances for uncollectible accounts of $1110 million and $12 million, respectively.

Depreciation

On July 15, 2013, TVA determined that Colbert Fossil Plant ("Colbert") Unit 5 will be idled on October 1, 2013. Colbert Unit 5 had been scheduled to idle on October 1, 2014. It is expected that the decision to idle Colbert Unit 5 on October 1, 2013 will increase depreciation expense by approximately $14 million during the fourth quarter of 2013 due to the acceleration of the idling date.

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. 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. 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 ~~future~~ payments to the DOE of as much as $~~250~~175 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. At ~~March 31,~~June 30, 2013, TVA had paid out approximately $106 million for this program and the obligation recorded was $346 million.

Insurance

In May 2013, TVA discontinued its directors and officers insurance program after determining that TVA's internal indemnification policies and procedures provided sufficient protection to TVA's directors and officers.

2. Impact of New Accounting Standards and Interpretations

Comprehensive Income. In June 2011, the Financial Accounting Standards Board ("FASB") issued guidance that requires adjustments to the presentation of TVA's financial information. The guidance eliminated the option to report comprehensive income and its components in the statement of changes in proprietary capital. The guidance required the presentation of net income and other comprehensive income in either one continuous statement or in two separate but consecutive statements. TVA chose the two statement approach. These changes became effective for TVA on October 1, 2012. The adoption of this guidance 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 ~~March 31,~~June 30, 2013, were not effective and had not been adopted by TVA.

Balance Sheet. In December 2011, 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. The guidance applies to derivative and other financial instruments and requires the disclosure of the gross amounts subject to offset, actual amounts offset in accordance with GAAP, and the related net exposure. These changes will become effective for TVA on October 1, 2013, and will be applied on a retrospective basis. ~~Since this~~This guidance relates solely to enhanced disclosures in the notes to the consolidated financial statements itand will 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 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 accumulated other comprehensive income 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 will become effective for TVA on October 1, 2013, and will be applied on a prospective basis. This guidance relates solely to enhanced disclosures and will not have an impact on TVA’s financial condition, results of operations, or cash flows.

1514

Table of Contents

3. Accounts Receivable, Net

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


Accounts Receivable, Net	Accounts Receivable, Net						Accounts Receivable, Net
	At March 31, 2013			At September 30, 2012			At June 30, 2013			At September 30, 2012
Power receivables	$	1,293		$	1,585		$	1,440		$	1,585
Other receivables	72			88			56			88
Allowance for uncollectible accounts	(4		)	(7		)	(4		)	(7		)
Accounts receivable, net	$	1,361		$	1,666		$	1,492		$	1,666

4. Inventories, Net

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


Inventories, Net	Inventories, Net						Inventories, Net
	At March 31, 2013			At September 30, 2012			At June 30, 2013			At September 30, 2012
Materials and supplies inventory	$	617		$	605		$	621		$	605
Fuel inventory	578			508			563			508
Emission allowance inventory	15			12			14			12
Allowance for inventory obsolescence	(32		)	(28		)	(34		)	(28		)
Inventories, net	$	1,178		$	1,097		$	1,164		$	1,097

5. Other Long-Term Assets

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


Other Long-Term Assets	Other Long-Term Assets				Other Long-Term Assets
	At March 31, 2013		At September 30, 2012		At June 30, 2013		At September 30, 2012
EnergyRight^®receivables	$	117	$	115	$	115	$	115
Loans and other long-term receivables, net	79		76		84		76
Currency swap asset	14		21		16		21
Coal contract derivative assets	2		107		4		107
Other	193		190		201		190
Total other long-term assets	$	405	$	509	$	420	$	509

TVA guarantees repayment on certain loans receivable from customers of TVA's distributors in association with the EnergyRight^® Solutions program. TVA sells the loans receivable to a third-party bank and has agreed with the bank to purchase any loan receivable that has been in default for 180 days or more or that TVA has determined is uncollectible. The loans receivable, and the associated obligation to purchase those loans, are shown in Other long-term assets and Other long-term liabilities, respectively, on TVA's consolidated balance sheets. The current portion of the loans receivable and the associated obligation to purchase those loans are shown in Current assets and Current liabilities, respectively, on TVA's consolidated balance sheets. At ~~March 31,~~June 30, 2013, the carrying amount of the loans receivable, net of discount, was approximately $~~151~~149 million. The carrying amount of the associated obligation to purchase those loans was approximately $~~186~~184 million. See Note 9.

1615

Table of Contents

6. 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 deferrals 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	Regulatory Assets and Liabilities				Regulatory Assets and Liabilities
	At March 31, 2013		At September 30, 2012		At June 30, 2013		At September 30, 2012
Current regulatory assets
Deferred nuclear generating units	$	236	$	237	$	237	$	237
Unrealized losses on commodity derivatives	174		310		176		310
Environmental agreements	89		87		74		87
Environmental cleanup costs - Kingston ash spill	72		72		72		72
Fuel cost adjustment receivable	13		68		—		68
Total current regulatory assets	584		774		559		774

Non-current regulatory assets
Deferred pension costs and other post-retirement benefits costs	5,331		5,517		5,237		5,517
Unrealized losses on interest rate derivatives	1,119		1,332		867		1,332
Nuclear decommissioning costs	890		914		922		914
Environmental cleanup costs - Kingston ash spill	756		797		738		797
Construction costs	619		619		619		619
Non-nuclear decommissioning costs	556		550		573		550
Deferred nuclear generating units	354		473		295		473
Environmental agreements	226		237		219		237
Unrealized losses on commodity derivatives	157		335		137		335
Other non-current regulatory assets	344		353		338		353
Total non-current regulatory assets	10,352		11,127		9,945		11,127
Total regulatory assets	$	10,936	$	11,901	$	10,504	$	11,901

Current regulatory liabilities
Fuel cost adjustment tax equivalents	$	177	$	173	$	176	$	173
Fuel cost adjustment liability					25		—
Unrealized gains on commodity derivatives	11		18		7		18
Total current regulatory liabilities	188		191		208		191

Non-current regulatory liabilities
Unrealized gains on commodity derivatives	3		109		4		109
Total non-current regulatory liabilities	3		109		4		109
Total regulatory liabilities	$	191	$	300	$	212	$	300

7. Variable Interest Entities

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 million secured note issuance (the “JSCCG notes”) and the issuance of $100 million of membership interests subject to mandatory redemption. The membership interests were purchased by John Sevier Holdco LLC ("Holdco"). Holdco is a special single-purpose entity, also formed in January 2012, established to acquire and hold the membership interests in JSCCG. A non-controlling interest in Holdco is held by a third party through nominal membership interests, to which none of the income or expenses of Holdco are allocated.

Table of Contents

The membership interests held by Holdco in JSCCG were purchased with proceeds from the issuance of $100 million of secured notes (the “Holdco notes") and are subject to mandatory redemption pursuant to scheduled amortizing, semi-annual

~~Table of Contents~~

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 the administrative or 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 is deemed to have a variable interest in each of these entities. Accordingly, TVA performs continual qualitative evaluations regarding which interest holders have the power to direct the activities that most significantly impact the economic performance of the entities and have the obligation to absorb losses or receive benefits that could be significant to the entities. The evaluations consider the purpose and design of the businesses, the risks that the businesses were designed to create and pass along to other entities, the activities of the businesses that can be directed and which party can direct them, and the expected relative impact of those activities on the economic performance of the businesses. TVA has the power to direct the activities of an entity when it has the ability to make key operating, investing and financing decisions, including, but not limited to, capital investment and the issuance or redemption of debt. Based on its analysis, TVA has determined 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 and Holdco as reflected in the Consolidated Balance Sheets are as follows:


JSCCG and Holdco Summary of Impact on Consolidated Balance Sheets	JSCCG and Holdco Summary of Impact on Consolidated Balance Sheets				JSCCG and Holdco Summary of Impact on Consolidated Balance Sheets
	At March 31, 2013		At September 30, 2012		At June 30, 2013		At September 30, 2012
Current liabilities
Accrued interest	$	10	$	10	$	22	$	10
Current maturities of long-term debt of variable interest entities	13		13		13		13
Total current liabilities	23		23		35		23
Long-term debt, net
Long-term debt of variable interest entities	975		981		975		981
Total long-term debt, net	975		981		975		981
Total liabilities	$	998	$	1,004	$	1,010	$	1,004

JSCCG’s and Holdco’s creditors do not have any recourse to the general credit of TVA. TVA does not have any obligations to provide financial support to JSCCG or Holdco other than as prescribed in the terms of the agreements related to this transaction.

8. Kingston Fossil Plant Ash Spill

The Event

In December 2008, one of the dredge cells at the Kingston Fossil Plant ("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 Environmental Protection Agency ("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 (final removal) will be completed in the ~~first quarter~~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 17 — Legal Proceedings Related to the Kingston Ash Spill and Civil Penalty and Natural Resource Damages for the Kingston Ash Spill.

Table of Contents

Financial Impact

Because of the uncertainty at this time of the final costs to complete the work prescribed by the ash disposal plan, a range of reasonable estimates has been developed by cost category. Known amounts, most likely scenarios, or the low end of

~~Table of Contents~~

the range for each category have been accumulated and evaluated to determine the total estimate. The range of costs varies from approximately $1.1 billion to approximately $1.2 billion.

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. As the estimate changes, additional costs may be deferred and charged to expense prospectively as they are collected in future rates.

As work continues to progress and more information is available, TVA will review its estimates and revise them as appropriate. TVA has accrued a portion of the estimated cost in current liabilities, with the remaining portion shown as a long-term liability on TVA's consolidated balance sheets. Amounts spent since the event through ~~March 31,~~June 30, 2013, totaled $~~908~~938 million. The remaining estimated liability at ~~March 31,~~June 30, 2013, was $~~217~~187 million.

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, or costs of remediating any mixed waste discovered during the ash removal process.~~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 asset retirement obligations ("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. TVA has received insurance proceeds of $50 million. 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. Any amounts received related to insurance settlements are being recorded as reductions to the regulatory asset and will reduce amounts collected in future rates.

9. Other Long-Term Liabilities

Other long-term liabilities consist primarily of liabilities related to certain derivative instruments as well as liabilities under agreements related to compliance with certain environmental regulations (see Note 17 — Environmental Agreements). The table below summarizes the types and amounts of Other long-term liabilities:

									Other Long-Term Liabilities
	At March 31, 2013		At September 30, 2012		At June 30, 2013		At September 30, 2012
Interest rate swap liabilities	$	1,510	$	1,723	$	1,258	$	1,723
Environmental agreements liability	226		237		219		237
EnergyRight^® purchase obligation	149		148		147		148
Currency swap liabilities	63		54		56		54
Commodity swap derivative liabilities					41		59
Coal contract derivative liabilities	52		205		27		205
Commodity swap derivative liabilities	41		59
Other	186		254		219		254
Total other long-term liabilities	$	2,227	$	2,680	$	1,967	$	2,680

TVA guarantees repayment on certain loans receivable from end-use customers in association with the EnergyRight^® Solutions program. TVA sells the loans receivable to a third-party bank and has agreed with the bank to purchase any loan receivable that has been in default for 180 days or more or that TVA has determined is uncollectible. As of ~~March 31,~~June 30, 2013, the carrying amount of the associated obligation to purchase those loans was approximately $~~186~~184 million, of which $37 million is current and included in Accounts payable and accrued liabilities. See Note 5.

1918

Table of Contents

10. Asset Retirement Obligations

During the ~~six~~nine months ended ~~March 31,~~June 30, 2013, TVA's total ARO liability increased $66149 million. The increase in the liability ~~was~~resulted from accretion and a change in estimate. These items were partially offset by ash area settlement projects that were conducted during the ~~six~~nine months ended ~~March 31,~~June 30, 2013. The nuclear and non-nuclear accretion were deferred as regulatory assets, and $2030 million of the related regulatory assets was amortized into expense as this amount was collected in rates.The change in estimate is a result of TVA's biennial update to its nuclear ARO in order to adjust for changes in expected labor factors, burial rates, and fuel expenses, among other factors. This review resulted in a $48 million increase to the nuclear ARO.


Reconciliation of Asset Retirement Obligation Liability	Reconciliation of Asset Retirement Obligation Liability									Reconciliation of Asset Retirement Obligation Liability

	Nuclear		Non-Nuclear			Total				Nuclear		Non-Nuclear			Total
Balance at September 30, 2012	$	2,208	$	1,081		$	3,289			$	2,208	$	1,081		$	3,289
Settlements (ash storage areas)	—		(15		)	(15		)		—		(25		)	(25		)
Accretion (recorded as regulatory asset)	61		20			81				93		33			126
Balance at March 31, 2013	$	2,269	$	1,086		$	3,355		^*
Change in estimate										48		—			48
Balance at June 30, 2013										$	2,349	$	1,089		$	3,438		^*

Note

* The current portion of ARO in the amount of $3134 million is included in Accounts payable and accrued ~~liabilities.~~liabilities at June 30, 2013.

11. Debt and Other Obligations

Debt Outstanding

Total debt outstanding at ~~March 31,~~June 30, 2013, and September 30, 2012, consisted of the following:


Debt Outstanding	Debt Outstanding						Debt Outstanding
	At March 31, 2013			At September 30, 2012			At June 30, 2013			At September 30, 2012
Short-term debt
Short-term debt, net	$	2,045		$	1,507		$	2,395		$	1,507
Current maturities of long-term debt of variable interest entities	13			13			13			13
Current maturities of power bonds	1,242			2,308			972			2,308
Total current debt outstanding, net	3,300			3,828			3,380			3,828
Long-term debt
Long-term debt of variable interest entities	975			981			975			981
Long-term power bonds	21,042			20,330			21,296			20,330
Unamortized discounts, premiums and other	(83		)	(61		)	(82		)	(61		)
Total long-term debt, net	21,934			21,250			22,189			21,250
Total outstanding debt	$	25,234		$	25,078		$	25,569		$	25,078

2019

Table of Contents

Debt Securities Activity

The table below summarizes the long-term debt securities activity for the period from October 1, 2012, to ~~March 31,~~June 30, 2013.

													Debt Securities Activity
	Date	Amount			Interest Rate		Date	Amount			Interest Rate

Issues
2012 Series B⁽¹⁾	December 2012	$	1,000		3.50	%	December 2012	$	1,000		3.50	%
electronotes^®	Second Quarter 2013	92			3.21	%	Second Quarter 2013	92			3.21	%
electronotes^®							Third Quarter 2013	13			3.15	%
Discount on debt issues		(25		)				(25		)
Total long-term debt issuances		$	1,067					$	1,080

Redemptions/Maturities⁽²⁾
2009 Series A	November 2012	$	2		2.25	%	November 2012	$	2		2.25	%
2009 Series B	December 2012	1			3.77	%	December 2012	1			3.77	%
1998 Series C	March 2013	1,359			6.00	%	March 2013	1,359			6.00	%
1999 Series A							May 2013	1			4.15	%
2009 Series A							May 2013	2			2.25	%
1998 Series D							June 2013	2			4.06	%
2009 Series B							June 2013	1			3.77	%
electronotes^®							First Quarter 2013	8			4.91	%
electronotes^®	First Quarter 2013	8			4.91	%	Second Quarter 2013	17			4.98	%
electronotes^®	Second Quarter 2013	17			4.98	%	Third Quarter 2013	24			4.18	%
Total redemptions/maturities		$	1,387					$	1,417

Notes

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

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

~~Putable Automatic Rate Reset Securities. The interest rate on the~~ ~~1999 Series A Putable Automatic Rate Reset Securities ("1999 Series A Bonds")~~ ~~was reset on May 1, 2013, from~~ ~~4.15 percent~~ to ~~3.96 percent~~. Because investors have the opportunity to put these securities to TVA in the event of a rate reset, and because the rates met the condition to reset as of March 31, 2013, TVA reclassified the outstanding principal balance of $~~271 million~~ ~~of 1999 Series A Bonds to current maturities of long-term debt at~~ ~~March 31, 2013. TVA redeemed $1 million~~ ~~of the 1999 Series A Bonds on May 1, 2013.~~

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 ~~2013~~2014 with a maturity date of September 30, ~~2013.~~2014. Access to this credit facility or other similar financing arrangements with the U.S. Treasury has been available to TVA since the 1960s. TVA plans to use the U.S. Treasury 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 ~~March 31,~~June 30, 2013 or September 30, 2012.

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 $0.5 billion credit facility matures on April 5, 2018. ~~The $0.5 billion~~ ~~credit facility replaced a previous $0.5 billion~~ ~~credit facility maturing on January 14, 2014. See~~ ~~Note 18~~ — ~~Credit Facility~~. 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 ~~March 31,~~June 30, 2013, there were $~~1.1~~1.0 billion of letters of credit outstanding under the facilities, and there were no borrowings outstanding. See Note 13 — Other Derivative Instruments — Collateral.

12. Lease/Leaseback Obligations

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

Table of Contents

produced by the combustion turbine facilities during the leaseback term, TVA accounted for the lease proceeds as financing

~~Table of Contents~~

obligations. At ~~March 31,~~June 30, 2013, and September 30, 2012, the outstanding leaseback obligations, related to CTs and QTE, were $~~780~~762 million and $825 million, respectively.

Seven States Power Corporation ("Seven States"), through its subsidiary, Seven States Southaven, LLC ("SSSL"), exercised its option to purchase from TVA an undivided 90 percent interest in a combined-cycle combustion turbine facility in Southaven, Mississippi. As part of interim joint-ownership arrangements, Seven States has the right at any time during the interim period, and for any reason, to require TVA to buy back SSSL's interest in the facility. The interim period under the joint-ownership arrangements was to expire on April 23, 2013. On April 18, 2013, TVA and Seven States, through SSSL, agreed to extend the expiration date of the interim joint ownership arrangements to September 5, 2013. The other material terms and conditions of the arrangements were not changed and remain in full force and effect. TVA intends to re-acquire SSSL's interest in the facility and the related assets either on or prior to the extended expiration date of September 5, 2013. The carrying amount of the Southaven obligation on TVA's consolidated balance sheets was approximately $~~370~~365 million at ~~March 31,~~June 30, 2013, and $378 million at September 30, 2012. OnAt ~~March 31,~~June 30, 2013, this obligation was recorded in Current portion of leaseback obligations on the Consolidated Balance Sheets.

13. Risk Management Activities and Derivative Transactions

TVA is exposed to various risks. These include risks related to commodity prices, investment prices, interest rates, currency exchange rates, inflation, and counterparty credit and performance risks. To help manage certain of these risks, TVA has entered into various derivative transactions, principally 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)	Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 1)													Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 1)
				Amount of Mark-to-Market⁽¹⁾ Gain (Loss) Recognized in Other Comprehensive Income (Loss)⁽²⁾ Three Months Ended March 31					Amount of Mark-to-Market Gain (Loss) Recognized in Other Comprehensive Income (Loss) Six Months Ended March 31								Amount of Mark-to-Market⁽¹⁾ Gain (Loss) Recognized in Other Comprehensive Income (Loss)⁽²⁾ Three Months Ended June 30					Amount of Mark-to-Market Gain (Loss) Recognized in Other Comprehensive Income (Loss) Nine Months Ended June 30
Derivatives in Cash Flow Hedging Relationship		Objective of Hedge Transaction	Accounting for Derivative Hedging Instrument	2013			2012		2013			2012			Objective of Hedge Transaction	Accounting for Derivative Hedging Instrument	2013		2012			2013			2012
Currency swaps		To protect against changes in cash flows caused by changes in foreign currency exchange rates (exchange rate risk)	Cumulative unrealized gains and losses are recorded in OCI and reclassified to interest expense to the extent they are offset by cumulative gains and losses on the hedged transaction	$	(49	)	$	21	$	(16	)	$	64		To protect against changes in cash flows caused by changes in foreign currency exchange rates (exchange rate risk)	Cumulative unrealized gains and losses are recorded in OCI and reclassified to interest expense to the extent they are offset by cumulative gains and losses on the hedged transaction	$	9	$	(36	)	$	(7	)	$	27

Notes

(1) Mark-to-Market ("MtM")

(2) Other Comprehensive Income (Loss) ("OCI")

2221

Table of Contents


Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2)	Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2)											Summary of Derivative Instruments That Receive Hedge Accounting Treatment (part 2)
		Amount of Gain (Loss) Reclassified from OCI to Interest Expense Three Months Ended March 31					Amount of Gain (Loss) Reclassified from OCI to Interest Expense Six Months Ended March 31						Amount of Gain (Loss) Reclassified from OCI to Interest Expense Three Months Ended June 30					Amount of Gain (Loss) Reclassified from OCI to Interest Expense Nine Months Ended June 30
Derivatives in Cash Flow Hedging Relationship		2013		2012			2013		2012				2013			2012		2013		2012
Currency swaps		$	63	$	(28	)	$	58	$	(26	)		$	(1	)	$	18	$	57	$	(7	)

Note

There were no ineffective portions or amounts excluded from effectiveness testing for any of the periods presented.

																													Summary of Derivative Instruments That Do Not Receive Hedge Accounting Treatment
			Amount of Gain (Loss) Recognized in Income on Derivatives Three Months Ended March 31⁽¹⁾						Amount of Gain (Loss) Recognized in Income on Derivatives Six Months Ended March 31⁽¹⁾								Amount of Gain (Loss) Recognized in Income on Derivatives Three Months Ended June 30⁽¹⁾						Amount of Gain (Loss) Recognized in Income on Derivatives Nine Months Ended June 30⁽¹⁾
Derivative Type	Objective of Derivative	Accounting for Derivative Instrument	2013			2012			2013			2012			Objective of Derivative	Accounting for Derivative Instrument	2013			2012			2013			2012
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.	$	—		$	—		$	—		$	—		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.	$	—		$	—		$	—		$	—

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.	—			(3		)	—			(16		)	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.	(2		)	(6		)	(2		)	(22		)

Commodity derivatives under financial trading program ("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.	(32		)	(88		)	(77		)	(144		)	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.	(21		)	(104		)	(99		)	(248		)

Note

(1) All of TVA's derivative instruments that do not receive hedge accounting treatment have unrealized gains (losses) that would otherwise be recognized in income

but instead are deferred as regulatory assets and liabilities. As such, there was no related gain (loss) recognized in income for these unrealized gains (losses) for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012.

2322

Table of Contents

																	Mark-to-Market Values of TVA Derivatives
	At March 31, 2013				At September 30, 2012				At June 30, 2013				At September 30, 2012
Derivatives that Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Currency swaps
£200 million Sterling	$	(37	)	Other long-term liabilities	$	(23	)	Other long-term liabilities	$	(36	)	Other long-term liabilities	$	(23	)	Other long-term liabilities
£250 million Sterling	14			Other long-term assets	21			Other long-term assets	16			Other long-term assets	21			Other long-term assets
£150 million Sterling	(26		)	Other long-term liabilities	(31		)	Other long-term liabilities	(20		)	Other long-term liabilities	(31		)	Other long-term liabilities

Derivatives that Do Not Receive Hedge Accounting Treatment:
	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation	Balance			Balance Sheet Presentation
Interest rate swaps
$1.0 billion notional	(1,101		)	Other long-term liabilities	(1,247		)	Other long-term liabilities	(926		)	Other long-term liabilities	(1,247		)	Other long-term liabilities
$476 million notional	(393		)	Other long-term liabilities	(458		)	Other long-term liabilities	(319		)	Other long-term liabilities	(458		)	Other long-term liabilities
$42 million notional	(16		)	Other long-term liabilities	(18		)	Other long-term liabilities	(13		)	Other long-term liabilities	(18		)	Other long-term liabilities
Commodity contract derivatives	(148		)	Other long-term assets $2; Other current assets $5; Other long-term liabilities $(52); Accounts payable and accrued liabilities $(103)	(267		)	Other long-term assets $107; Other current assets $12; Other long-term liabilities $(205); Accounts payable and accrued liabilities $(181)	(111		)	Other long-term assets $4; Other current assets $4; Other long-term liabilities $(27); Accounts payable and accrued liabilities $(92)	(267		)	Other long-term assets $107; Other current assets $12; Other long-term liabilities $(205); Accounts payable and accrued liabilities $(181)
FTP
Margin cash account⁽¹⁾	19			Other current assets	43			Other current assets	18			Other current assets	43			Other current assets
Derivatives under FTP	(161		)	Other long-term assets $1; Other current assets $(82); Other long-term liabilities $(41); Accounts payable and accrued liabilities $(39)	(229		)	Other long-term assets $2; Other current assets $(104); Other long-term liabilities $(60); Accounts payable and accrued liabilities $(67)	(181		)	Other long-term assets $0; Other current assets $(98); Other long-term liabilities $(41); Accounts payable and accrued liabilities $(42)	(229		)	Other long-term assets $2; Other current assets $(104); Other long-term liabilities $(60); Accounts payable and accrued liabilities $(67)

Note

(1) In accordance with certain credit terms, TVA uses leverage to trade financial instruments under the FTP. Therefore, the margin cash account balance does not represent 100 percent of the net market value of the derivative positions outstanding as shown in the Derivatives Under Financial Trading Program table.

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 as of ~~March 31,~~June 30, 2013:


Currency Swaps Outstanding At March 31, 2013
Currency Swaps Outstanding At June 30, 2013				Currency Swaps Outstanding At June 30, 2013
Effective Date of Currency Swap Contract	Associated TVA Bond Issues Currency Exposure	Expiration Date of Swap	Overall Effective Cost to TVA		Associated TVA Bond Issues Currency Exposure	Expiration Date of Swap	Overall Effective Cost to TVA
1999	£200 million	2021	5.81%		£200 million	2021	5.81%
2001	£250 million	2032	6.59%		£250 million	2032	6.59%
2003	£150 million	2043	4.96%		£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.

2423

Table of Contents

Derivatives Not Receiving Hedge Accounting Treatment

Interest Rate Derivatives. In March 2012, the counterparty to TVA's only outstanding swaption agreement exercised its option to enter into an interest rate swap with TVA, effective April 15, 2012, requiring TVA to make fixed-rate payments to the counterparty of ~~8.25 percent~~ ~~and the counterparty to make floating rate payments to TVA based on LIBOR until April 15, 2042. These payments are based on a notional principal amount of $1.0 billion~~ ~~and began on July 15, 2012.~~

TVA uses regulatory accounting treatment to defer the MtM gains and losses on ~~the~~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~~Consolidated Statements of ~~operations.~~Operations.

For the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, the changes in market value of the interest rate swaps resulted in deferred unrealized gains of $99252 million and $~~213~~465 million, respectively.

Commodity Derivatives. TVA enters into certain derivative contracts for coal and natural gas that require physical delivery of the contracted quantity of the commodity. TVA marks to market all such contracts. At ~~March 31,~~June 30, 2013, and September 30, 2012, TVA's coal contract derivatives had net market values of $~~(148)~~(109) million and $(267) million, respectively, which TVA deferred as regulatory assets or liabilities on a gross basis. At ~~March 31,~~June 30, 2013, TVA's coal contract derivatives had terms of up to five years. At ~~March 31,~~June 30, 2013, and September 30, 2012, TVA's natural gas derivative contracts had total market values of less than $12 million. At ~~March 31,~~June 30, 2013, these natural gas derivative contracts had terms of up to two years.


Commodity Contract Derivatives	Commodity Contract Derivatives										Commodity Contract Derivatives
	At March 31, 2013					At September 30, 2012					At June 30, 2013					At September 30, 2012
	Number of Contracts	Notional Amount	Fair Value (MtM)			Number of Contracts	Notional Amount	Fair Value (MtM)			Number of Contracts	Notional Amount	Fair Value (MtM)			Number of Contracts	Notional Amount	Fair Value (MtM)
Coal contract derivatives	21	43 million tons	$	(148	)	23	46 million tons	$	(267	)	23	44 million tons	$	(109	)	23	46 million tons	$	(267	)
Natural gas contract derivatives	14	45 million mmBtu	$	—		25	51 million mmBtu	$	—		28	49 million mmBtu	$	(2	)	25	51 million mmBtu	$	—

Derivatives Under FTP. TVA has an FTP under which it purchases and sells 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 ~~March 31,~~June 30, 2013, the risks hedged under the FTP were the economic risks associated with the prices of natural gas, fuel oil and crude oil. All futures contracts and option contracts under the FTP have expired. Swap contracts under the FTP had remaining terms of five years or less.

2524

Table of Contents

																	Derivatives Under Financial Trading Program
	At March 31, 2013				At September 30, 2012				At June 30, 2013				At September 30, 2012
	Notional Amount	Fair Value (MtM) (in millions)			Notional Amount	Fair Value (MtM) (in millions)			Notional Amount	Fair Value (MtM) (in millions)			Notional Amount	Fair Value (MtM) (in millions)
Natural gas (in mmBtu)
Futures contracts	—	$	—		—	$	—		—	$	—		—	$	—
Swap contracts	195,127,500	(164		)	294,462,500	(232		)	165,662,500	(179		)	294,462,500	(232		)
Option contracts	—	—			—	—			—	—			—	—
Natural gas financial positions	195,127,500	$	(164	)	294,462,500	$	(232	)	165,662,500	$	(179	)	294,462,500	$	(232	)

Fuel oil/crude oil (in barrels)
Futures contracts	—	$	—		—	$	—		—	$	—		—	$	—
Swap contracts	1,184,000	3			1,390,000	4			1,313,000	(2		)	1,390,000	4
Option contracts	—	—			—	—			—	—			—	—
Fuel oil/crude oil financial positions	1,184,000	$	3		1,390,000	$	4		1,313,000	$	(2	)	1,390,000	$	4

Coal (in tons)
Futures contracts	—	$	—		—	$	—		—	$	—		—	$	—
Swap contracts	—	—			—	—			—	—			—	—
Option contracts	—	—			—	—			—	—			—	—
Coal financial positions	—	$	—		—	$	—		—	$	—		—	$	—

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 only realized gains or losses to match the delivery period of the underlying commodity. In addition to the open commodity derivatives disclosed above, TVA had closed derivative contracts with market values of $~~(6)~~(9) million at ~~March 31,~~June 30, 2013, and $(21) million at September 30, 2012. 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:

													FTP Unrealized Gains (Losses)

FTP unrealized gains (losses) deferred as regulatory liabilities (assets)	At March 31, 2013			At September 30, 2012			At June 30, 2013			At September 30, 2012

Natural gas	$	(164	)	$	(232	)	$	(179	)	$	(232	)
Fuel oil/crude oil	3			4			(2		)	4

																									FTP Realized Gains (Losses)

	For the Three Months Ended March 31						For the Six Months Ended March 31						For the Three Months Ended June 30						For the Nine Months Ended June 30
(Increase) decrease in fuel expense	2013			2012			2013			2012			2013			2012			2013			2012

Natural gas	$	(20	)	$	(16	)	$	(48	)	$	(16	)	$	(13	)	$	(53	)	$	(60	)	$	(69	)
Fuel oil/crude oil	—			2			2			7			—			1			2			9
Coal	—			—			(1		)	1			—			—			(1		)	1

2625

Table of Contents

																									FTP Realized Gains (Losses)

	For the Three Months Ended March 31						For the Six Months Ended March 31						For the Three Months Ended June 30						For the Nine Months Ended June 30
(Increase) decrease in purchased power expense	2013			2012			2013			2012			2013			2012			2013			2012

Natural gas	$	(13	)	$	(74	)	$	(32	)	$	(136	)	$	(8	)	$	(53	)	$	(40	)	$	(189	)

Other Derivative Instruments

Investment Fund Derivatives. Investment funds consist primarily of funds held in the Nuclear Decommissioning Trust ("NDT"), Asset Retirement Trust ("ART"), and Supplemental Executive Retirement Plan ("SERP"). All securities in the trusts are classified as trading. See Note 14 — Investments 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 ~~March 31,~~June 30, 2013, and September 30, 2012, the fair value of derivative instruments in these trusts was not material to TVA's consolidated financial statements.

Collateral. TVA's interest rate swaps and currency swaps contain contract provisions that require a party to post collateral (in a form such as cash or a letter of credit) when the party's liability balance under the agreement exceeds a certain threshold. At ~~March 31,~~June 30, 2013, the aggregate fair value of all derivative instruments with credit-risk related contingent features that were in a liability position was $~~1.6~~1.3 billion. TVA's collateral obligations at ~~March 31,~~June 30, 2013, under these arrangements was $~~1.1~~1.0 billion, for which TVA had posted $~~1.1~~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 ("S&P") or Moody's Investors Service ("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 municipal and cooperative ~~distributor~~ customers, 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 ~~two~~ ~~municipal and cooperative customers that represented~~ ~~18 percent~~ ~~of total outstanding accounts receivable at~~ ~~March 31, 2013. TVA had concentrations of accounts receivable from~~ three municipal and cooperative customers that represented 26 percent of total outstanding accounts receivable at June 30, 2013 and at September 30, 2012. Power sales to TVA's largest directly served industrial customer represented five percent of TVA's total operating revenues for the ~~six~~nine months ended ~~March 31,~~June 30, 2013. This customer's senior unsecured credit ratings are currently rated below investment grade by both S&P and Moody's. As a result of its credit ratings, this customer has provided credit assurance to TVA under the terms of its power contract. On May 24, 2013, the customer announced the cessation of enrichment activities at one of its sites. TVA and the customer subsequently completed agreements to extend power sales to facilitate the cessation of enrichment activities and to support non-enrichment activities at the site for June and July 2013 at a greatly reduced level. These sales may continue to be extended.

Credit of Derivative Counterparties. TVA has entered into derivative contracts for hedging purposes, and TVA's NDT fund and 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 ~~March 31,~~June 30, 2013, all of TVA's currency swaps, interest rate swaps, and

Table of Contents

commodity derivatives under the FTP were with counterparties whose Moody's credit rating was Baa1 or higher. At

~~Table of Contents~~

~~March 31,~~June 30, 2013, 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 B3 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 11 ~~different~~multiple suppliers at ~~March 31,~~June 30, 2013. 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 ~~all~~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 440 megawatts ("MW") of summer net capability from a lignite-fired generating plant. TVA has determined that the supplier has the equivalent of a non-investment grade credit rating; therefore, the supplier has provided credit assurance to TVA under the terms of the agreement.

The senior unsecured credit ratings of TVA's largest supplier of uranium enrichment services, which is also TVA's largest directly served industrial customer, ~~directly served,~~ are currently rated below investment grade by both S&P and Moody's. Any nonperformance by this company could result in TVA incurring additional costs.

14. Fair Value Measurements

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

Valuation Techniques

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



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

A financial instrument's level within the fair value hierarchy (where Level 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 assets, all changes in fair value of these assets and liabilities have been reflected as changes in regulatory assets, regulatory liabilities, or accumulated other comprehensive loss on TVA's Consolidated Balance Sheet as of ~~March 31,~~June 30, 2013, and Consolidated Statements of Changes in Proprietary Capital for the ~~six~~nine

2827

Table of Contents

months ended ~~March 31,~~June 30, 2013. Except for gains and losses on SERP assets, there has been no impact to the Consolidated Statements of Operations or the Consolidated Statements of Cash Flows related to these fair value measurements.

Investments

At ~~March 31,~~June 30, 2013, Investment funds were composed of $1.6 billion of securities classified as trading and measured at fair value and $21 million of equity investments not required to be measured at fair value. Trading securities are held in the NDT, ART, and SERP. The NDT holds funds for the ultimate decommissioning of TVA's nuclear power plants. The ART holds funds primarily for the costs related to the future closure and retirement of TVA's other long-lived assets. 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 rules applicable to the qualified defined benefit pension plan. The NDT, ART and SERP are invested in ~~securities~~a mix of investments generally designed to achieve a return in line with overall equity market performance.

The NDT, ART, and SERP 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, and cash securities and certain derivative instruments are measured based on quoted exchange prices in active markets and are classified as Level 1 valuations. Fixed-income investments, high-yield fixed-income investments, currencies, and most derivative instruments are non-exchange traded and are classified as Level 2 valuations. These measurements are based on market and income approaches with observable market inputs.

Private 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 $~~166~~157 million at ~~March 31,~~June 30, 2013. These investments have no redemption or limited redemption options and may also have imposed restrictions on the NDT’s ability to liquidate its investment. 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 and SERP consist of 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 ~~liquidated~~redeemed at the measurement date NAV and are classified as Level 2 valuations. Required notification periods range from zero to 30 days. The funds can be redeemed unless doing so would violate regulations to which the fund is subject, would be unreasonable or impracticable, or would be seriously prejudicial to the fund.

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)									Unrealized Investment Gains (Losses)
		For the Three Months Ended March 31				For the Six Months Ended March 31					For the Three Months Ended June 30						For the Nine Months Ended June 30
	Financial Statement Presentation	2013		2012		2013		2012		Financial Statement Presentation	2013			2012			2013		2012

SERP	Other income (expense)	$	1	$	2	$	1	$	3	Other income (expense)	$	(1	)	$	(1	)	$	—	$	2
NDT	Regulatory asset	36		60		49		118		Regulatory asset	(42		)	(21		)	16		97
ART	Regulatory asset	14		15		17		25		Regulatory asset	(6		)	(8		)	16		17

~~Table of Contents~~

Currency and Interest Rate Swaps

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

Table of Contents

Commodity Contract Derivatives and Commodity Derivatives Under FTP

Commodity Contract Derivatives. These contracts are classified as Level 3 valuations and are valued based on income approaches. TVA develops an overall coal price forecast using 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.

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 13 — 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 of TVA (for liabilities) and the counterparty (for assets), by applying a credit valuation adjustment ("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 2011) 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 $2 million decrease in the fair value of assets and a $1 million decrease in the fair value of liabilities at ~~March 31,~~June 30, 2013.

3029

Table of Contents

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 as of ~~March 31,~~June 30, 2013, and September 30, 2012. 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 March 31, 2013
Fair Value Measurements At June 30, 2013												Fair Value Measurements At June 30, 2013
Assets	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting⁽¹⁾			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting⁽¹⁾			Total

Investments
Equity securities	$	146	$	—	$	—	$	—		$	146	$	136	$	—	$	—	$	—		$	136
Debt securities
U.S. government corporations and agencies	68		85		—		—			153		43		80		—		—			123
Corporate debt securities	—		241		—		—			241		—		143		—		—			143
Residential mortgage-backed securities	—		15		—		—			15		—		13		—		—			13
Commercial mortgage-backed securities	—		10		—		—			10		—		6		—		—			6
Collateralized debt obligations	—		18		—		—			18		—		22		—		—			22
Private partnerships	—		—		137		—			137		—		—		150		—			150
Commingled funds⁽²⁾
Equity security commingled funds	—		728		—		—			728		—		714		—		—			714
Debt security commingled funds	—		119		—		—			119		—		263		—		—			263
Total investments	214		1,216		137		—			1,567		179		1,241		150		—			1,570
Currency swaps	—		14		—		—			14		—		16		—		—			16
Commodity contract derivatives	—		—		7		—			7		—		—		8		—			8
Commodity derivatives under FTP
Swap contracts	—		97		—		(91		)	6		—		112		—		(110		)	2

Total	$	214	$	1,327	$	144	$	(91	)	$	1,594	$	179	$	1,369	$	158	$	(110	)	$	1,596

Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting⁽¹⁾			Total		Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting⁽¹⁾			Total

Currency swaps	$	—	$	63	$	—	$	—		$	63	$	—	$	56	$	—	$	—		$	56
Interest rate swaps	—		1,510		—		—			1,510		—		1,258		—		—			1,258
Commodity contract derivatives	—		—		155		—			155		—		2		117		—			119
Commodity derivatives under FTP
Swap contracts	—		258		—		(91		)	167		—		293		—		(110		)	183

Total	$	—	$	1,831	$	155	$	(91	)	$	1,895	$	—	$	1,609	$	117	$	(110	)	$	1,616

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 broker.

(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 exclusively composed of one class of security are classified in that category. Commingled funds comprising multiple classes of securities are classified as “other commingled funds.”

3130

Table of Contents



Fair Value Measurements At September 30, 2012
Assets	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting⁽¹⁾			Total

Investments
Equity securities	$	173	$	—	$	—	$	—		$	173
Debt securities
U.S. government corporations and agencies	59		103		—		—			162
Corporate debt securities	—		197		—		—			197
Residential mortgage-backed securities	—		20		—		—			20
Commercial mortgage-backed securities	—		6		—		—			6
Collateralized debt obligations	—		12		—		—			12
Private partnerships	—		—		53		—			53
Commingled funds⁽²⁾
Equity security commingled funds	—		657		—		—			657
Debt security commingled funds	—		182		—		—			182
Total investments	232		1,177		53		—			1,462
Currency swaps	—		21		—		—			21
Commodity contract derivatives	—		—		119		—			119
Commodity derivatives under FTP
Swap contracts	—		123		—		(115		)	8

Total	$	232	$	1,321	$	172	$	(115	)	$	1,610

Liabilities	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting⁽¹⁾			Total

Currency swaps	$	—	$	54	$	—	$	—		$	54
Interest rate swaps	—		1,723		—		—			1,723
Commodity contract derivatives	—		—		386		—			386
Commodity derivatives under FTP
Swap contracts	—		351		—		(115		)	236

Total	$	—	$	2,128	$	386	$	(115	)	$	2,399

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 broker.

3231

Table of Contents

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
	For the Three Months Ended March 31									For the Six Months Ended March 31									For the Three Months Ended June 30									For the Nine Months Ended June 30
	Private Partnerships			Commodity Contract Derivatives			Interest Rate Swaption			Private Partnerships			Commodity Contract Derivatives			Interest Rate Swaption			Private Partnerships			Commodity Contract Derivatives			Interest Rate Swaption			Private Partnerships			Commodity Contract Derivatives			Interest Rate Swaption
Balance at beginning of period	$	28		$	4		$	(1,128	)	$	22		$	239		$	(1,077	)	$	36		$	(311	)	$	(993	)	$	22		$	239		$	(1,077	)
Purchases	7			—			—			13			—			—			9			—			—			21			—			—
Issuances	—			—			—			—			—			—			—			—			—			—			—			—
Sales	—			—			—			(1		)	—			—			—			—			—			(2		)	—			—
Settlements	—			—			—			—			—			—			—			—			993			—			—			1,077
Net unrealized gains (losses) deferred as regulatory assets and liabilities	1			(315		)	135			2			(550		)	84			—			(20		)	—			4			(570		)	—
Balance at March 31, 2012	$	36		$	(311	)	$	(993	)	$	36		$	(311	)	$	(993	)
Balance at June 30, 2012																			$	45		$	(331	)	$	—		$	45		$	(331	)	$	—

Balance at beginning of period	$	66		$	(224	)	$	—		$	53		$	(267	)	$	—		$	137		$	(148	)	$	—		$	53		$	(267	)	$	—
Purchases	70			—			—			83			—			—			9			—			—			93			—			—
Issuances	—			—			—			—			—			—			—			—			—			—			—			—
Sales	(1		)	—			—			(2		)	—			—			(1		)	—			—			(3		)	—			—
Settlements	—			—			—			—			—			—			—			—			—			—			—			—
Net unrealized gains (losses) deferred as regulatory assets and liabilities	2			76			—			3			119			—			5			39			—			7			158			—
Balance at March 31, 2013	$	137		$	(148	)	$	—		$	137		$	(148	)	$	—
Balance at June 30, 2013																			$	150		$	(109	)	$	—		$	150		$	(109	)	$	—

TVA has used interest rate swaption agreements in the past to protect against decreases in the value of embedded call provisions on certain of its Bond issues. A swaption is a derivative instrument that grants a third party the right to enter into a receive fixed/pay variable interest rate swap agreement with TVA based on the interest rate of the underlying Bond issue. In

March 2012, the counterparty to TVA's only outstanding interest rate swaption agreement exercised its option to enter into an interest rate swap agreement, effective April 15, 2012. In association with exercising its option to enter into the interest rate swap with TVA, the counterparty was required to pay TVA $60 million on the effective date of the transaction. The net deferred unrealized gains and losses on the interest rate swaption were assigned to the resulting interest rate swap upon the effective date of the exercise.

Prior to its conversion to an interest rate swap, the swaption was classified as a Level 3 valuation and was valued based on an income approach. The valuation was computed using a broker-provided pricing model utilizing interest and volatility rates. While most of the fair value measurement was based on observable inputs, volatility for TVA's swaption was generally unobservable. Therefore, the valuation was derived from an observable volatility measure with adjustments.

There were no realized gains or losses related to the instruments measured at fair value using significant unobservable inputs that affected net income during the ~~six~~nine months ended ~~March 31,~~June 30, 2013. All unrealized gains and losses related to these instruments have been reflected as increases or decreases in regulatory assets and liabilities. See Note 6.

3332

Table of Contents

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

March 31, 2013

Valuation Technique(s)

Unobservable Inputs

Range

Fair Value at

June 30, 2013

Valuation Technique(s)

Unobservable Inputs

Range

Assets

Commodity contract derivatives

Discounted cash flow

Credit risk

9.4

Discounted cash flow

Credit risk

Pricing model

Coal supply and demand

1.0 - 1.1 billion tons/year

Pricing model

Coal supply and demand

0.9 - 1.0 billion tons/year

Long-term market prices

$13.75 - $86.83/ton

Long-term market prices

$14.45 - $90.31/ton

Liabilities

Commodity contract derivatives

155

Pricing model

Coal supply and demand

1.0 - 1.1 billion tons/year

117

Pricing model

Coal supply and demand

0.9 - 1.0 billion tons/year

Long-term market prices

$13.75 - $86.83/ton

Long-term market prices

$14.45 - $90.31/ton

* 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 values of the financial instruments held at ~~March 31,~~June 30, 2013, and September 30, 2012, 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 ~~March 31,~~June 30, 2013, and September 30, 2012, were as follows:

																			Estimated Values of Financial Instruments Not Recorded at Fair Value
		At March 31, 2013				At September 30, 2012					At June 30, 2013				At September 30, 2012
	Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Valuation Classification	Carrying Amount		Fair Value		Carrying Amount		Fair Value
EnergyRight^®receivables (including current portion)	Level 2	$	151	$	151	$	150	$	150	Level 2	$	149	$	149	$	150	$	150

Loans and other long-term receivables, net	Level 2	$	79	$	72	$	76	$	70	Level 2	$	84	$	78	$	76	$	70

EnergyRight^®purchase obligation (including current portion)	Level 2	$	186	$	213	$	185	$	209	Level 2	$	184	$	208	$	185	$	209

Long-term outstanding power bonds (including current maturities), net	Level 2	$	22,201	$	27,172	$	22,577	$	28,041	Level 2	$	22,186	$	24,514	$	22,577	$	28,041

Long-term debt of variable interest entities (including current maturities)	Level 2	$	988	$	1,113	$	994	$	1,116	Level 2	$	988	$	1,033	$	994	$	1,116

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 values of the EnergyRight^®Solutions receivables and loans and other long-term receivables are estimated by determining the present values of future cash flows using discount rates equal to lending rates for similar loans made to borrowers with similar credit ratings and similar remaining maturities, where applicable.

The fair value of the 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 values of the EnergyRight^®Solutions purchase obligation and other long-term debt are 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.

3433

Table of Contents

15. Other Income (Expense), Net

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


Other Income (Expense), Net	Other Income (Expense), Net											Other Income (Expense), Net
	For the Three Months Ended March 31						For the Six Months Ended March 31					For the Three Months Ended June 30						For the Nine Months Ended June 30
	2013			2012			2013		2012			2013			2012			2013		2012
External services												$	6		$	—		$	17	$	2
Interest income	$	6		$	2		$	11	$	4		5			27			17		14
External services	4			(1		)	11		3
Gains (losses) on investments	2			2			3		4			—			(1		)	2		3
Miscellaneous	(1		)	(17		)	1		(16		)	(1		)	(5		)	—		(3		)
Total other income (expense), net	$	11		$	(14	)	$	26	$	(5	)	$	10		$	21		$	36	$	16

16. 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 certain retirees' medical coverage, other postemployment benefits, such as workers' compensation, and the SERP.

The components of net periodic benefit cost and other amounts recognized as changes in regulatory assets for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012, were as follows:


Components of TVA’s Benefit Plans	Components of TVA’s Benefit Plans																								Components of TVA’s Benefit Plans
	For the Three Months Ended March 31												For the Six Months Ended March 31												For the Three Months Ended June 30												For the Nine Months Ended June 30
	Pension Benefits						Other Post-Retirement Benefits						Pension Benefits						Other Post-retirement Benefits						Pension Benefits						Other Post-Retirement Benefits						Pension Benefits						Other Post-retirement Benefits
	2013			2012			2013			2012			2013			2012			2013			2012			2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	43		$	34		$	7		$	4		$	77		$	69		$	12		$	9		$	38		$	34		$	6		$	5		$	115		$	103		$	18		$	14
Interest cost	111			123			6			9			234			245			15			18			117			123			8			9			351			368			23			27
Expected return on plan assets	(105		)	(109		)	—			—			(214		)	(218		)	—			—			(107		)	(109		)	—			—			(321		)	(327		)	—			—
Amortization of prior service cost	(5		)	(6		)	(1		)	(1		)	(11		)	(12		)	(3		)	(3		)	(6		)	(6		)	(2		)	(1		)	(17		)	(18		)	(5		)	(4		)
Recognized net actuarial loss	98			90			6			8			188			180			13			15			95			90			6			8			283			270			19			23
Total net periodic benefit cost recognized	$	142		$	132		$	18		$	20		$	274		$	264		$	37		$	39		$	137		$	132		$	18		$	21		$	411		$	396		$	55		$	60

During the ~~six~~nine months ended ~~March 31,~~June 30, 2013, TVA did not make contributions to its qualified defined benefit pension plan. TVA does not separately set aside assets to fund other benefit costs, but rather funds such costs on an as-paid basis. TVA provided approximately $2634 million and $2031 million for other benefit costs during the ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012, respectively.

17. Legal Proceedings

General. At June 30, 2013, TVA had accrued approximately $~~340~~319 million of ~~potential~~probable losses with respect to Legal Proceedings at and estimated the range of these losses to be from $~~March 31, 2013~~319 million to $349 million. Of ~~this~~the accrued amount, $~~226~~219 million is included in Other long-term liabilities, $~~104~~90 million is included in Accounts payable and accrued liabilities, and $10 million is included in Regulatory assets. TVA is currently unable to estimate any amount or any range of amounts of reasonably possible losses, ~~in excess of the established accruals,~~ 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, a Federal Facilities Compliance Agreement with the EPA and a consent decree with Alabama, Kentucky, North Carolina, Tennessee, and three

Table of Contents

environmental advocacy groups: the Sierra Club, National Parks Conservation Association, and Our Children's Earth Foundation

~~Table of Contents~~

~~(collectively,~~ (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 sulfur dioxide ("SO₂") and nitrogen oxides ("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 existing and possible claims against TVA based on alleged New Source Review and associated violations were waived and cannot be brought against TVA. Some possible claims for sulfuric acid mist and greenhouse gas ("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 ~~March 31,~~June 30, 2013 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, with the costs charged to expense as they are collected in rates.

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~~Fossil Plant ("John Sevier")Clean Air Act ("CAA") permit is expected to be narrowed in scope.

Legal Proceedings Related to the Kingston Ash Spill. Seventy-eight lawsuits based on the Kingston ash spill have been filed in the United States District Court for the Eastern District of Tennessee. Fifteen of these lawsuits have been dismissed, and 63 lawsuits are active and in various stages of litigation. Plaintiffs are residents, businesses, and property owners in the Kingston area and allege tort claims for damage to property (for example, nuisance, strict liability, trespass, and negligence), with some plaintiffs also alleging claims for personal injury, business loss, and inverse condemnation. Plaintiffs seek unspecified compensatory and punitive damages, court orders to clean up properties and other relief. TVA is the only active defendant in these actions.

A bench trial on the issue of dike failure causation in the seven earliest cases was held in September and October 2011 ("Phase I trial"). Plaintiffs in the 56 remaining cases have agreed to be bound by the Phase I trial record and decision. In August 2012, the court issued its Phase I decision, finding that certain actions by TVA contributed to the ash spill. On November 20, 2012, the court ordered the parties to participate in mediation within 120 days of the issuance of the order. ~~On March 21, 2013, the~~The court has extended the mediation period twice: by ~~an additional~~ 120 days. on March 21, 2013, and by 75 days on July 12, 2013. If the case is not resolved through mediation, the case will proceed to the damages phase ("Phase II") trial, during which the individual plaintiffs must prove both that they incurred damages and that the ash spill was the cause of the damages. The date for the Phase II trial has not yet been set.

TVA has received several notices of intent to sue under various environmental statutes from both individuals and environmental groups, but no such suits have been filed.

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 has satisfied $10 million, and TDEC has approved environmental projects valued at $2 million as a credit against the penalty amount. In January 2011, TVA entered into 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 damage claim associated with the Kingston ash spill. As part of this memorandum of agreement, TVA agreed to pay $250 thousand each year for three years as a down payment on the amount of natural resource damages ultimately established, and to reimburse TDEC and the U.S. Fish and Wildlife Service for their costs.

Case Involving Tennessee Valley Authority Retirement System. In March 2010, eight current and former participants in and beneficiaries of the Tennessee Valley Authority Retirement System ("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 cost of living adjustment ("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. The plaintiffs allege that TVA's actions violated the TVARS Board members' fiduciary duties to the plaintiffs (and the purported class) and the plaintiffs' contractual rights, among other claims. The plaintiffs sought, among other things, unspecified damages, an order directing the TVARS Board to rescind the amendments, and the appointment of a seventh TVARS Board member. Five of the six individual defendants filed motions to dismiss the lawsuit, while the remaining defendant filed an answer to the complaint. In July 2010, TVA moved to intervene in the suit in the event it was not dismissed. In September 2010, the district court dismissed the breach of fiduciary duty claim against the directors without prejudice, allowing the plaintiffs to file an amended complaint within 14 days against TVARS and TVA but not the individual directors. The plaintiffs previously had voluntarily withdrawn their constitutional claims, so the court also dismissed those claims without prejudice. The court dismissed

Table of Contents

with prejudice the plaintiffs' claims for breach of contract, violation of the Internal Revenue Code, and appointment of a seventh TVARS Board member.

~~Table of Contents~~

In September 2010, the plaintiffs filed an amended complaint against TVARS and TVA. 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 that will likely take a significant amount of time~~mediation. In July 2013, the court granted the plaintiffs' motion to ~~complete. The mediation began in September 2012 and is taking place over a series of meetings.~~reopen the lawsuit.

Case Arising out of Hurricane Katrina. In April 2006, TVA was added as a defendant to a class action lawsuit brought in the United States District Court for the Southern District of Mississippi by 14 Mississippi residents allegedly injured by Hurricane Katrina. The plaintiffs sued seven large oil companies and an oil company trade association, three large chemical companies and a chemical trade association, and 31 large companies involved in the mining and/or burning of coal, alleging that the defendants' GHG emissions contributed to global warming and were a proximate and direct cause of Hurricane Katrina's increased destructive force. Action by the United States Supreme Court in January 2011 ended this case in a manner favorable to TVA.

However, in May 2011, under a Mississippi state statute that permits the re-filing of lawsuits that were dismissed on procedural grounds, the plaintiffs filed another lawsuit in the United States District Court for the Southern District of Mississippi against the same and additional defendants, again alleging that the defendants' GHG emissions contributed to global warming and were a proximate and direct cause of Hurricane Katrina's increased destructive force. The court dismissed the lawsuit in March 2012 for a variety of reasons, including that the lawsuit presented a non-justiciable political question and that all of the claims were preempted by the CAA. The plaintiffs ~~have~~ appealed the ~~dismissal~~case to the United States Court of Appeals for the Fifth ~~Circuit.~~Circuit, which affirmed the dismissal on May 14, 2013.

Case Involving the Nuclear Regulatory Commission ("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 Waste Confidence Decision ("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 (a) hold in abeyance all pending reactor licensing decisions that would depend upon the WCD and (b) 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 NRC Order") preventing the issuance of a final licensing decision in all proceedings affected by the petition, including Watts Bar Nuclear Plant ("Watts Bar") Unit 2 and Bellefonte Nuclear Plant ("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 NRC's completion of an environmental review and generic rulemaking addressing the shortcomings identified by the D.C. Circuit. ~~The NRC has decided to support the update of its WCD with an~~A draft rule and Environmental Impact Statement ~~and has started this process~~addressing the D.C. Circuit decision were issued by the NRC staff for NRC comment in June 2013. The NRC is currently scheduled to address this issue by September 2014.

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 Atomic Safety and Licensing Board ("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 ~~matters.~~in abeyance pending further direction from the NRC.

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, ~~Bellefonte Efficiency and Sustainability Team ("BEST")~~,BEST, BREDL, and Southern Alliance for Clean Energy ("SACE") submitted a joint petition for intervention and a request for a hearing. The ~~Atomic Safety and Licensing Board ("ASLB")~~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

Table of Contents

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 NRC's Waste Confidence Decision. This contention is being held in abeyance pursuant to the August NRC Order.

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

~~Table of Contents~~

TVA indicate there is no longer a genuine issue of material fact in connection with SACE's remaining aquatic impact contention. ~~SACE and the NRC staff filed their answers to the motion in December 2011; SACE opposed TVA's motion while the NRC staff supported it.~~ In March 2012, the ASLB denied TVA's motion. ~~TVA anticipates that~~In July 2013, SACE filed a ~~hearing on the matter will likely be held in the latter part of 2013.~~ 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. Similarly, this contention is being held in abeyance pursuant to the August NRC Order.

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 ~~Clean Air Act ("CAA")~~CAA permit issued to TVA for operation of the John ~~Sevier Fossil Plant ("John Sevier")~~.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.

Kingston 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 Water Quality, Oil, and Gas Board ("TN Board"). In addition to its allegation that Tennessee violated the Clean Water Act by failing to set specific limits on certain toxic discharges, the Sierra Club alleges that no discharges from the pond infrastructure should be allowed because zero-discharge scrubbers exist. TDEC is the defendant in the challenge, and TVA has intervened in support of TDEC's decision to issue the permit. The matter was set for a hearing before the TN Board in February 2011, but has since been stayed by agreement of the parties.

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. Petitioners' motion for summary judgment was denied, but TVA and TDEC appealed two findings in the decision denying summary judgment to the TN Board. This appeal was scheduled to be heard in January 2013, but was removed from the agenda by order of another administrative law judge. ~~This~~The case iswas scheduled for a hearing before the TN Board in May ~~2013.~~2013, but the hearing was postponed.

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. Administrative discovery is underway.

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

Table of Contents

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 Nuclear Plant ("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.

~~Table of Contents~~

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 2.206 Petition. The NRC has not yet rendered a decision regarding the petition.

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.

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 ~~the~~ ~~National Environmental Policy Act ("NEPA")~~NEPA when it decided to install additional emission controls and construct an associated landfill at the Gallatin Fossil Plant. ~~The plaintiffs~~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.

~~18. Subsequent Events~~

~~Bond Issuance~~

~~On April 4, 2013, TVA issued $13 million~~ This case has been transferred to the United States District Court for the Eastern District of ~~3.15 percent~~ ~~electronotes~~^® ~~due April 15, 2033 and callable beginning~~

~~April 15, 2017, CUSIP number 88059TFR7. The notes were issued at~~ ~~100 percent~~ ~~of par value.~~Tennessee.

~~Credit Facility~~Case Involving Colbert Fossil Plant.

On April 5,1, 2013, the Alabama Department of Environmental Management ("ADEM") filed suit in the Circuit Court of Colbert County, Alabama, alleging that unauthorized discharges from TVA's Colbert Fossil Plant were violating the Alabama Water Pollution Control Act. On May 13, 2013, TVA and ADEM entered into a ~~new~~consent decree which resolves this lawsuit. The decree requires, among other things, that TVA continue remediation efforts TVA had begun prior to the suit being filed and stop using an unlined landfill after a lined landfill is approved and constructed. TVA also agreed to pay $~~0.5 billion~~ ~~revolving credit facility that matures on April 5, 2018. This credit facility replaces TVA’s previous $0.5 billion~~ ~~credit facility maturing on January 14, 2014. See~~ ~~Note 11~~150 thousand.

~~Bond Redemption~~

~~On April 8, 2013, TVA redeemed all of its 2010~~ ~~4.30 percent~~ ~~electronotes~~^® ~~due March 15, 2025, CUSIP number 88059TEZ0. The notes were redeemed at~~ ~~100 percent~~ ~~of par value for a total of $22 million~~.

~~Putable Automatic Rate Reset Securities~~

~~On May 1, 2013, TVA issued notice that the interest rate on the~~ ~~1998 Series D Putable Automatic Rate Reset Securities ("1998 Series D Bonds")~~ ~~will reset from~~ ~~4.06 percent~~ to ~~3.83 percent~~ ~~on June 1, 2013. In conjunction with the reset, holders of the 1998 Series D Bonds may request redemption of the Bonds at par value through May 22, 2013, for redemption on June 1, 2013.~~

3938

Table of Contents

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

(Dollars in millions except where noted)

Management’s Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") explains the results of operations and general financial condition of the Tennessee Valley Authority ("TVA"). The MD&A should be read in conjunction with the accompanying unaudited consolidated financial statements and TVA's Annual Report on Form 10-K for the fiscal year ended September 30, 2012 (the “Annual Report”).

Executive Overview

~~Weather continued to be the primary driver affecting TVA's sales and results of operations~~Sales were five percent lower for the ~~periods~~three month period ended ~~March 31,~~June 30, 2013, and relatively flat for the nine month period ended June 30, 2013 as compared ~~with~~to the same periods of 2012. Weather patterns ~~were closer to normal~~produced less cooling degree days in the spring and early summer of 2013 as compared to ~~milder weather in 2012 which~~the same periods of 2012. This resulted in ~~higher~~lower sales to local power companies that distribute TVA ~~electricity.~~electricity during the three months ended June 30, 2013 as compared to the same period of 2012, but TVA had higher sales during the nine months ended June 30, 2013 as compared to the same period of 2012 due to greater heating degree days during the fall and winter of 2013. Sales to industrial customers lagged during these same periods primarily due to TVA's largest directly served customer which began ceasing operations in May 2013 and to a lesser extent from a slower economy in the TVA service area. TVA also continued to increase its off-system sales as a result of having excess generation available for resale during 2013. ~~Sales to industrial customers lagged during the three and six month periods ended~~ ~~March 31, 2013, as compared with the same periods of 2012. Also, sales to TVA's largest directly served customer decreased as the customer continued to curtail operations during the second quarter of 2013.~~

TVA had net ~~income~~losses for the three and nine months ended ~~March 31,~~June 30, 2013 of $5412 million and ~~net losses for the six months ended March 31, 2013, of~~ $~~191~~203 million, respectively, as compared with net losses of $9423 million and $~~267~~290 million for the same periods of ~~2012. Revenues increased primarily due~~2012 as rates are designed to provide more revenues during the fourth quarter. Base revenue decreased $122 million for the three month period and $172 million for the nine month period ended June 30, 2013 as compared to the same periods of the prior year. Revenue from the recovery of fuel ~~costs. Although base revenues were $36~~costs decreased $52 million ~~higher~~ for the three months ended ~~March 31,~~June 30, 2013 as compared to the same period of the prior year ~~base~~due in part to higher hydroelectric generation. However, revenue ~~decreased $49~~from the recovery of fuel costs increased $127 million for the ~~six~~nine months ended ~~March 31,~~June 30, 2013 as compared to the same period of 2012.

Fuel and purchased power costs ~~increased~~decreased for the three months ~~and six months~~ ended ~~March 31,~~June 30, 2013,, as compared to the same ~~periods~~period of 2012 primarily due to ~~the increase in the market price of natural gas and decreased lower-cost nuclear generation due to planned outages. Greater~~greater hydroelectric generation resulting from increased rainfall and runoff during 2013 as compared to 2012, which helped mitigate the increase in fuel costs and the need to purchase power to meet demand.

~~Although TVA experienced a slight increase in sales of electricity in~~ Fuel and purchased power costs increased for the nine months ended June 30, 2013, as compared to the same period of 2012 primarily due to increased higher-cost fuel generation and decreased lower-cost nuclear generation primarily due to the steam generator replacement outage at Sequoyah Nuclear Plant ("Sequoyah").

TVA continues to focus on reducing costs in response to ~~a decline~~lower electricity sales in the TVA service area in recent periods, and lower expected demand ~~for electricity both regionally~~growth in the region and across the United States. By implementing sustainable efficiency efforts to reduce routine operating and maintenance expense, TVA plans to achieve its goal of becoming one of the nation's leading providers of low-cost and cleaner energy by 2020.

TVA ~~continued~~continues to experience operational challenges with respect to its generating plants. Although the Nuclear Regulatory Commission ("NRC") reported in July 2013 that the immediate problems related to a 2011 major safety violation finding at TVA's Browns Ferry Nuclear Plant ("Browns Ferry") ~~is still operating under a heightened degree~~have been fixed, the NRC will continue increased inspections to ensure improvements are made and maintained.

Longer term, TVA faces challenges related to fluctuating fuel prices and compliance with current and emerging environmental laws and regulations. In order to comply with these laws and regulations, TVA may install clean air equipment on coal-fired units and replace generating capacity of ~~oversight by the~~ ~~Nuclear Regulatory Commission ("NRC"). Additionally,~~idled coal-fired units with cleaner-emissions nuclear and gas-fired units. TVA continues to work with the NRC to address identified hydrology issues at Watts Bar Nuclear Plant ("Watts Bar") and ~~Sequoyah Nuclear Plant ("Sequoyah"). Longer term, TVA faces~~Sequoyah. Addressing these challenges ~~related to fluctuating fuel prices and compliance with current andemerging environmental laws and regulations. In order to comply with these laws and regulations, TVA may install clean air equipment on coal-fired units andreplace generating capacity of idled coal-fired units with cleaner-emissions nuclear and gas-fired units. Meeting theseneeds~~ will require significant capital expenditures on TVA's ~~part, but~~part. TVA ~~is constrained by the TVA Act which authorizes TVA toissues~~anticipates that capital spending needs can be met with a combination of bonds, notes, or other evidences of indebtedness ("Bonds") ~~in an amount not to exceed $30.0 billion outstanding at anyone time. Without a legislative solution, this limitation may require TVA to seek alternative financing arrangements.~~, lease arrangements, energy prepayments, additional power revenues through rate increases, cost reductions, or other ways.

Table of Contents

Results of Operations

Sales of Electricity

The following table compares TVA’s energy sales statistics for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012:


Sales of Electricity (millions of kWh)	Sales of Electricity (millions of kWh)												Sales of Electricity (millions of kWh)
	Three Months Ended March 31						Six Months Ended March 31						Three Months Ended June 30						Nine Months Ended June 30
	2013	2012	Change		Percent Change		2013	2012	Change		Percent Change		2013	2012	Change		Percent Change		2013	2012	Change		Percent Change
Municipalities and cooperatives	34,025	31,251	2,774		8.9	%	64,687	61,726	2,961		4.8	%	31,390	32,609	(1,219	)	(3.7	)%	96,077	94,335	1,742		1.8	%
Industries directly served	7,447	8,316	(869	)	(10.4	)%	15,002	16,341	(1,339	)	(8.2	)%	6,539	7,531	(992	)	(13.2	)%	21,541	23,872	(2,331	)	(9.8	)%
Federal agencies and other	826	497	329		66.2	%	1,722	1,026	696		67.8	%	1,024	967	57		5.9	%	2,746	1,993	753		37.8	%
Total sales of electricity	42,298	40,064	2,234		5.6	%	81,411	79,093	2,318		2.9	%	38,953	41,107	(2,154	)	(5.2	)%	120,364	120,200	164		0.1	%

~~Table of Contents~~

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

Degree Days
2013
Normal⁽¹⁾
Percent Variation 2012
Normal⁽¹⁾
Percent Variation 2013 2012 Percent Change
Heating Degree Days
Three Months Ended March 31 1,856
1,812
2.4 % 1,285
1,833
(29.9 )% 1,856
1,285
44.4 %
Six Months Ended March 31 3,071
3,115
(1.4 )% 2,455
3,136
(21.7 )% 3,071
2,455
25.1 %

Cooling Degree Days
Three Months Ended March 31 6
12
(50.0 )% 72
12
500.0 % 6
72
(91.7 )%
Six Months Ended March 31 38
79
(51.9 )% 118
79
49.4 % 38
118
(67.8 )%



Degree Days
	2013	Normal⁽¹⁾	Percent Variation		2012	Normal⁽¹⁾	Percent Variation		2013	2012	Percent Change
Heating Degree Days
Three Months Ended June 30	261	228	14.5	%	130	228	(43.0	)%	261	130	100.8	%
Nine Months Ended June 30	3,332	3,343	(0.3	)%	2,585	3,364	(23.2	)%	3,332	2,585	28.9	%

Cooling Degree Days
Three Months Ended June 30	598	586	2.0	%	757	586	29.2	%	598	757	(21.0	)%
Nine Months Ended June 30	637	666	(4.4	)%	875	666	31.4	%	637	875	(27.2	)%

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 ~~increased~~decreased 2.2 billion kilowatt hours ("kWh") ~~and 2.3 billion kWh~~ for the three ~~and six~~ months ended ~~March 31,~~June 30, 2013, compared to the three ~~and six~~ months ended ~~March 31,~~June 30, 2012, primarily due to ana decrease in sales to both municipalities and cooperatives and industries directly served. The decrease in sales to municipalities and cooperatives was primarily the result of relatively normal weather for the three months ended June 30, 2013, as compared to warmer than normal weather for the three months ended June 30, 2012. Cooling degree days were only 2.0 percent above normal for three months ended June 30, 2013, as compared to 29.2 percent above normal for the three months ended June 30, 2012. The decrease in sales to industries directly served was primarily due to decreased demand from TVA's largest directly served industrial customer, which began ceasing operations during the third quarter of 2013 (see 2013 Key Initiatives and Challenges — Customers/Counterparties Risk).

Sales of electricity increased 164 million kWh for the nine months ended June 30, 2013, compared to the nine months ended June 30, 2012, primarily due to increases in sales to both municipalities and cooperatives and federal agencies and other.

The increase in sales to municipalities and ~~cooperatives. Sales to municipalities and~~ cooperatives increased by 2.8 billion kWh for the three months ended March 31, 2013, and increased by 3.0 billion kWh for the six months ended March 31, 2013, as compared to the same periods in 2012. The increases werewas primarily related to the milder than normal ~~weather for~~winter during the ~~three and six~~nine months ended ~~March 31,~~June 30, 2012, compared to the relatively normal ~~weather for~~winter during the ~~three and six~~nine months ended ~~March 31,~~June 30, 2013. ~~The milder weather is evidenced by a 44 percent increase in heating~~Heating degree days were 23.2 percent below normal during the ~~three~~nine months ended ~~March 31, 2013, as~~June 30, 2012, compared to 0.3 percent below normal during the ~~three~~nine months ended ~~March 31, 2012. When comparing the six months ended March 31, 2013, to the six months ended March 31, 2012, there~~June 30, 2013. Offsetting these increases was a ~~25 percent increase~~decrease in heating degree days. The customers of municipalities and cooperatives are largely residential and commercial customers whose usage of electricity is typically more temperature-sensitive than that of industrial customers. An increase in sales to federal agencies and other was attributed to higher off-system sales, as TVA had excess generation available for resale. These increases were partially offsetdemand by industries directly served driven by decreased demand from ~~industries directly served, primarily by~~ TVA's largest directly served industrial ~~customer.~~customer, which began ceasing operations during the third quarter of 2013 (see 2013 Key Initiatives and Challenges — Customers/Counterparties Risk).

Table of Contents

Financial Results

The following table compares operating results for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012:


Summary Consolidated Statements of Operations	Summary Consolidated Statements of Operations															Summary Consolidated Statements of Operations
	Three Months Ended March 31							Six Months Ended March 31								Three Months Ended June 30								Nine Months Ended June 30
	2013		2012			Percent Change		2013			2012			Percent Change		2013			2012			Percent Change		2013			2012			Percent Change
Operating revenues	$	2,741	$	2,604		5.3	%	$	5,320		$	5,172		2.9	%	$	2,602		$	2,777		(6.3	)%	$	7,922		$	7,949		(0.3	)%
Operating expenses	2,380		2,358			0.9	%	4,903			4,789			2.4	%	2,324			2,499			(7.0	)%	7,228			7,288			(0.8	)%
Operating income	361		246			46.7	%	417			383			8.9	%	278			278			—	%	694			661			5.0	%
Other income, net	11		(14		)	178.6	%	26			(5		)	620.0	%	10			21			(52.4	)%	36			16			125.0	%
Interest expense, net	318		326			(2.5	)%	634			645			(1.7	)%	300			322			(6.8	)%	933			967			(3.5	)%
Net income (loss)	$	54	$	(94	)	157.4	%	$	(191	)	$	(267	)	28.5	%	$	(12	)	$	(23	)	47.8	%	$	(203	)	$	(290	)	30.0	%

~~Table of Contents~~

Operating Revenues. Operating revenues for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012, consisted of the following:


Operating Revenues	Operating Revenues												Operating Revenues
	Three Months Ended March 31						Six Months Ended March 31						Three Months Ended June 30						Nine Months Ended June 30
	2013		2012		Percent Change		2013		2012		Percent Change		2013		2012		Percent Change		2013		2012		Percent Change
Sales of electricity
Municipalities and cooperatives	$	2,350	$	2,160	8.8	%	$	4,539	$	4,303	5.5	%	$	2,227	$	2,339	(4.8	)%	$	6,766	$	6,643	1.9	%
Industries directly served	323		382		(15.4	)%	645		750		(14.0	)%	302		366		(17.5	)%	946		1,115		(15.2	)%
Federal agencies and other	36		27		33.3	%	74		56		32.1	%	43		36		19.4	%	118		92		28.3	%
Total sales of electricity	2,709		2,569		5.4	%	5,258		5,109		2.9	%	2,572		2,741		(6.2	)%	7,830		7,850		(0.3	)%
Other revenue	32		35		(8.6	)%	62		63		(1.6	)%	30		36		(16.7	)%	92		99		(7.1	)%
Total operating revenues	$	2,741	$	2,604	5.3	%	$	5,320	$	5,172	2.9	%	$	2,602	$	2,777	(6.3	)%	$	7,922	$	7,949	(0.3	)%

Operating revenues ~~increased $137~~decreased $175 million and ~~$148~~$27 million in the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, respectively, compared to the three and ~~six~~nine months ended ~~March 31,~~June 30, 2012, due to the following:


	Three Month Change		Six Month Change			Three Month Change			Nine Month Change
Fuel cost recovery	$	97	$	179		$	(52	)	$	127
Base revenue	36		(49		)	(122		)	(172		)
Other	4		18			(1		)	18
Total	$	137	$	148		$	(175	)	$	(27	)

Operating revenues ~~increased $137~~decreased $175 million for the three months ended ~~March 31,~~June 30, 2013, compared to the three months ended ~~March 31,~~June 30, 2012, ~~primarily~~ due to a $97 million increase in fuel cost recovery and a $36 million increase in base revenue. Of the $97 million increase in fuel cost recovery, $57 million was due to higher fuel rates and $40 million was due to an increase in sales of electricity. The $36 million increase in base revenue was primarily attributable to an increase in sales of electricity.

Operating revenues increased $148 million for the six months ended March 31, 2013, compared to the six months ended March 31, 2012, primarily due to a $179 million increase in fuel cost recovery and an $18 million increase in other revenue sources. Of the $179 million increase in fuel cost recovery, $143 million was due to higher fuel rates and $36 million was due to an increase in sales of electricity. The increase of $18 million in other revenue sources was attributable to higher off-system sales, as TVA had excess generation available for resale. Partially offsetting these increases was a $49$122 million decrease in base revenue ~~resulting~~and a $52 million decrease in ~~part~~fuel cost recovery. Both the $122 million decrease in base revenue and the $52 million decrease in fuel cost recovery were primarily attributable to a decrease in the sales of electricity.

Operating revenues decreased $27 million for the nine months ended June 30, 2013, compared to the nine months ended June 30, 2012. The change was primarily due to a $172 million decrease in base revenue resulting from a decrease in the effective base rate. The decrease in the effective base rate was partially the result of a change in distributor wholesale rate elections ~~(see below).~~as described below. Offsetting the decrease was an increase of $127 million in fuel cost recovery primarily due to higher fuel rates. Additionally, offsetting the decrease was an $18 million increase in other revenue sources as a result of higher off-system sales, as TVA had excess generation available for resale.

In August 2010, the TVA Board approved the implementation of a new wholesale rate structure. That structure provided for two wholesale rate options, a default time-of-use ("TOU") option and a seasonal demand and energy ("SDE") option. The SDE option was to serve as an interim transition rate and terminate in September 2012. Based on customer request for additional optionality, the TVA Board approved two additional wholesale structures for distributor consideration: a modified ~~time-of-use~~time-

Table of Contents

of-use ("MTOU") structure and a modified seasonal demand and energy ("MSDE") structure. The proposed options were designed to better align wholesale rates with TVA’s underlying cost to provide service. TVA allowed distributors to elect one of these wholesale rate structures and make retail adjustments consistent with their wholesale elections. Distributor elections went into effect October 1, 2012, as follows: 142 chose the MTOU structure, six chose the default TOU structure, and seven chose the MSDE structure. As expected, aligning rates with the cost of service reduced overall effective base rates during transition and winter months, in comparison to the same period of 2012, and is expected to produce higher revenues during the summer months.

~~Table of Contents~~

Operating Expenses. Operating expenses for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012, consisted of the following:


Operating Expenses	Operating Expenses												Operating Expenses
	Three Months Ended March 31						Six Months Ended March 31						Three Months Ended June 30						Nine Months Ended June 30
	2013		2012		Percent Change		2013		2012		Percent Change		2013		2012		Percent Change		2013		2012		Percent Change
Fuel	$	672	$	524	28.2	%	$	1,466	$	1,164	25.9	%	$	652	$	683	(4.5	)%	$	2,118	$	1,847	14.7	%
Purchased power	288		329		(12.5	)%	533		648		(17.7	)%	263		277		(5.1	)%	796		925		(13.9	)%
Operating and maintenance	876		863		1.5	%	1,795		1,743		3.0	%	866		882		(1.8	)%	2,662		2,625		1.4	%
Depreciation and amortization	408		493		(17.2	)%	836		934		(10.5	)%	412		505		(18.4	)%	1,248		1,439		(13.3	)%
Tax equivalents	136		149		(8.7	)%	273		300		(9.0	)%	131		152		(13.8	)%	404		452		(10.6	)%
Total operating expenses	$	2,380	$	2,358	0.9	%	$	4,903	$	4,789	2.4	%	$	2,324	$	2,499	(7.0	)%	$	7,228	$	7,288	(0.8	)%

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 (millions of kWh)	Power Supply from TVA-Operated Generation Facilities and Purchased Power (millions of kWh)												Power Supply from TVA-Operated Generation Facilities and Purchased Power (millions of kWh)
	Three Months Ended March 31						Six Months Ended March 31						Three Months Ended June 30						Nine Months Ended June 30
	2013			2012			2013			2012			2013			2012			2013			2012
Coal-fired	14,648	34	%	11,405	27	%	32,299	39	%	23,866	30	%	14,501	36	%	16,164	39	%	46,801	38	%	40,030	33	%
Nuclear	13,151	31	%	13,830	34	%	23,740	29	%	28,507	35	%	13,755	35	%	12,910	31	%	37,495	31	%	41,417	34	%
Hydroelectric	5,606	13	%	4,736	12	%	9,019	11	%	8,714	11	%	4,671	12	%	1,389	3	%	13,690	11	%	10,103	8	%
Natural gas and/or oil-fired	3,873	9	%	3,851	9	%	7,683	9	%	6,843	8	%	2,234	6	%	4,732	11	%	9,916	8	%	11,576	9	%
Renewable resources (non-hydro)	1	—	%	2	—	%	5	—	%	10	—	%	1	—	%	7	—	%	5	—	%	17	—	%
Total TVA-operated generation facilities	37,279	87	%	33,824	82	%	72,746	88	%	67,940	84	%	35,162	89	%	35,202	84	%	107,907	88	%	103,143	84	%
Purchased power	5,707	13	%	7,300	18	%	10,070	12	%	12,905	16	%	4,411	11	%	6,698	16	%	14,482	12	%	19,596	16	%
Total power supply	42,986	100	%	41,124	100	%	82,816	100	%	80,845	100	%	39,573	100	%	41,900	100	%	122,389	100	%	122,739	100	%

Fuel expense ~~increased $148~~decreased $31 million during the three months ended ~~March 31,~~June 30, 2013, as compared to the same period of the prior year, primarily due to the utilization of ~~more~~less expensive generation resources. During the three month period ended ~~March 31,~~June 30, 2013, TVA completed a nuclear refueling outage on one unit at Sequoyah, which included a steam generator replacement project, and began an additional refueling outage on one unit at Browns Ferry, compared to one nuclear refueling outage during the same period of the prior year, which contributedconventional hydroelectric generation increased by 226 percent, primarily due to a ~~five percent decrease in nuclear generation. A 28~~108 percent increase in ~~coal-fired~~rainfall and a 171 percent increase in runoff within the Tennessee River Basin. Hydroelectric generation ~~helped~~is TVA's least expensive type of generation. In addition, due primarily to ~~offset the~~higher market prices of natural gas, TVA decreased its natural gas-fired generation by 53 percent. The use of less expensive generation resources and lower sales of electricity resulted in a decrease in ~~nuclear generation. Additionally,~~fuel expense of $67 million. However, this was offset by a $36 million increase in fuel expense as a result of the higher market prices for the natural gas ~~caused a 35 percent increase in~~that was used during the average cost of gas-fired generation. The increase in coal-fired generation and the increase in the average cost of gas-fired generation contributed to a $102 million increase in fuel expense. Higher sales of electricity led to an increase in overall generation and accounted for the remaining $46 million of the increase in fuel expense.period.

Purchased power expense decreased ~~$41~~$14 million during the three months ended ~~March 31,~~June 30, 2013, as compared to the same period of the prior year, primarily due to a 2234 percent decrease in the volume of power purchased. Higher market prices for natural gas contributed to the volume decrease, as ~~TVA’s~~TVA's primary source of purchased power is natural gas-fired generation. This reduced purchased power expense by ~~$72~~$94 million, but the higher market prices for the power that was purchased offset this reduction by $80 million.

Operating and maintenance expense ~~increased~~decreased by ~~$13~~$16 million for the three months ~~ended March 31,~~June 30, 2013, as compared to the same period of the prior year. The increase was primarily attributable to a $17 million increase in nuclear expense and a $10 million increase in pension benefit expense. The increase in nuclear expense was driven by outage-dependent projects and other maintenance expenses that occurred during the steam generator replacement project at Sequoyah. The increase in pension benefit expenseCoal-fired operations was the ~~result~~primary driver of the ~~use of a lower assumed discount rate~~decrease with 105 fewer planned outage days for coal-fired units, due in ~~the actuarial calculation of pension liabilities. Offsetting these increases was a $19 million decrease in coal-fired operation expenses, due~~part to the retirement or idling of ~~several coal-fired~~less efficient units at ~~Johnsonville Fossil Plant ("Johnsonville")~~, ~~John Sevier Fossil Plant ("John Sevier"), and~~ ~~Widows Creek Fossil Plant ("Widows Creek")~~ during 2012 and the first quarter of 2013.

Table of Contents

Depreciation and amortization expense decreased ~~$85~~$93 million for the three months ended ~~March 31,~~June 30, 2013, as compared to the same period of the prior year, primarily due to a decrease in the amount of accelerated depreciation that was recognized on certain coal-fired units that were idled during 2012 and the first quarter of 2013.

~~Table of Contents~~

Tax equivalents expense decreased ~~$13~~$21 million in the three months ended ~~March 31,~~June 30, 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.

Fuel expense increased ~~$302~~$271 million during the ~~six~~nine months ended ~~March 31,~~June 30, 2013, as compared to the same period of the prior year, primarily due to the utilization of more expensive generation resources. During the ~~six~~nine month period ended ~~March 31,~~June 30, 2013, TVA completed ~~three~~four nuclear refueling outages on units at Watts Bar, Browns Ferry, and Sequoyah, which included a steam generator replacement project, ~~and began a fourth~~compared to two nuclear refueling ~~outage~~outages on ~~another unit~~units at Browns Ferry ~~compared to one nuclear refueling outage at~~and Sequoyah during the same period of the prior ~~year, which~~year. This contributed to a 17nine percent decrease in nuclear generation. A 3517 percent increase in coal-fired generation ~~and a 12 percent increase in gas-fired generation helped to~~ offset the decrease in nuclear generation and contributed to a ~~$214~~$248 million increase in fuel expense. ~~Higher sales of electricity led~~While coal-fired generation contributed to ~~an increase in overall generation and accounted for the remaining $88 million of~~ the increase in fuel ~~expense.~~expense, this was mitigated due to a 32 percent increase in conventional hydroelectric generation, primarily due to a 27 percent increase in rainfall and a 33 percent increase in runoff within the Tennessee River Basin.

Purchased power expense decreased ~~$115~~$129 million during the ~~six~~nine months ended ~~March 31,~~June 30, 2013, as compared to the same period of the prior year, primarily due to a 2226 percent decrease in the volume of power purchased. Higher market prices for natural gas contributed to the volume decrease, as ~~TVA’s~~TVA's primary source of purchased power is natural gas-fired generation. ~~This~~Lower volume reduced purchased power expense by ~~$142~~$241 million, but the higher market prices for the power that was purchased offset this reduction by $112 million.

Operating and maintenance expense increased ~~by $52~~$37 million ~~for~~in the ~~six~~nine months ended ~~March 31,~~June 30, 2013, as compared to the same period of the prior year. The increase was primarily attributable to a ~~$149~~$145 million increase in nuclear ~~expense. There were four~~expense related to more planned nuclear refueling outages ~~during the six months ended March 31, 2013, compared to one during the same period of the prior year. Additionally, there were increases in nuclear~~as well as increased outage projects and ~~other~~ scheduled maintenance ~~and labor costs. This increase was partially offset by a $59 million decrease in coal-fired operations, related to fewer outage and project expenses. In~~during the ~~six~~nine months ended ~~March 31,~~June 30, 2013 ~~there were 68 percent fewer planned outage days for coal-fired units~~ as compared to the same period of the prior year. This increase was partially offset by a $75 million decrease in coal-fired operations due to approximately 600 fewer planned outage days for coal-fired units compared to the same period in the prior year. In addition, ~~with the idling of units at Johnsonville, John Sevier, and Widows Creek during 2012 and the first quarter of 2013, coal-fired~~ scheduled maintenance expense decreased ~~$37~~$34 million in the ~~six~~nine months ended ~~March 31,~~June 30, 2013, compared to the same period of the prior ~~year.~~year due in part to the retirement or idling of less efficient units during 2012 and the first quarter of 2013.

Depreciation and amortization expense decreased ~~$98~~$191 million for the ~~six~~nine months ended ~~March 31,~~June 30, 2013, as compared to the same period of the prior year, primarily due to a decrease in the amount of accelerated depreciation recognized for certain coal-fired units to be idled. ~~Several~~Incremental depreciation associated with the idling of coal-fired units ~~at Johnsonville and John Sevier were idled during 2012 and the first quarter of 2013, which resulted in accelerated depreciation of $126~~was $236 million for the ~~six~~nine months ended ~~March 31,~~June 30, 2012, compared to ~~only $32~~$20 million ~~of accelerated depreciation~~ for the ~~six~~nine months ended ~~March 31, 2013 on the same units at Johnsonville and John Sevier.~~June 30, 2013.

Tax equivalents expense decreased ~~$27~~$48 million in the ~~six~~nine months ended ~~March 31,~~June 30, 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.

4443

Table of Contents

Interest Expense. Interest expense and interest rates for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012, were as follows:

																																	Interest Expense
	Three Months Ended March 31								Six Months Ended March 31								Three Months Ended June 30								Nine Months Ended June 30
	2013			2012			Percent Change		2013			2012			Percent Change		2013			2012			Percent Change		2013			2012			Percent Change
Interest Expense⁽¹⁾																	��
Interest expense	$	359		$	368		(2.4	)%	$	714		$	726		(1.7	)%	$	343		$	366		(6.3	)%	$	1,057		$	1,092		(3.2	)%
Allowance for funds used during construction and nuclear fuel expenditures	(41		)	(42		)	(2.4	)%	(80		)	(81		)	(1.2	)%	(43		)	(44		)	(2.3	)%	(124		)	(125		)	(0.8	)%
Net interest expense	$	318		$	326		(2.5	)%	$	634		$	645		(1.7	)%	$	300		$	322		(6.8	)%	$	933		$	967		(3.5	)%

	2013			2012			Percent Change		2013			2012			Percent Change		2013			2012			Percent Change		2013			2012			Percent Change
Interest Rates (average)
Long-term outstanding power bonds⁽²⁾	5.777		%	5.753		%	0.4	%	5.767		%	5.753		%	0.2	%	5.713		%	6.090		%	(6.2	)%	5.750		%	5.859		%	(1.9	)%
Long-term debt of variable interest entities	4.875		%	4.829		%	1.0	%	4.875		%	4.829		%	1.0	%	4.875		%	4.819		%	1.2	%	4.875		%	4.824		%	1.1	%
Discount notes	0.085		%	0.002		%	4,150.0	%	0.104		%	0.001		%	10,300.0	%	0.082		%	0.084		%	(2.4	)%	0.094		%	0.063		%	49.2	%
Blended	5.498		%	5.662		%	(2.9	)%	5.455		%	5.671		%	(3.8	)%	5.202		%	5.549		%	(6.3	)%	5.370		%	5.640		%	(4.8	)%

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 above and interest expense for those periods.

(3) While the average interest rates increased for the long-term outstanding power bonds and the discount notes, the impact of adding the long-term debt of variable interest entities to the blended interest rate calculation decreased the blended interest rate in the three and six months ended March 31, 2013.

Net interest expense decreased $8$22 million for the three months ended ~~March 31,~~June 30, 2013 as compared to the same period of the prior year. This was primarily attributable to a decrease in the average interest rate.

Net interest expense decreased $34 million for the nine months ended June 30, 2013 as compared to the same period of the prior year. This was primarily attributable to a decrease in interest expense of ~~$18~~$62 million as a result of a decrease in the average balance of long-term ~~debt.~~debt and a decrease in the average interest rate. This was partially offset by a ~~$10 million increase in interest expense primarily due to an increase in amortization of debt reacquisition cost as a result of prior year refinancing.~~

Net interest expense decreased $11 million for the six months ended March 31, 2013 as compared to the same period of the prior year. This was primarily attributable to a decrease in interest expense of $40 million as a result of a decrease in the average balance of long-term debt. This was partially offset by a $29$28 million increase in interest expense primarily due to an increase in amortization of debt reacquisition cost as a result of prior year refinancing and due to the financing of the John Sevier Combined Cycle Facility ("John Sevier CCF"). See Note 7.

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 also include a $150 million credit facility with the United States ("U.S.") Treasury, three revolving credit facilities totaling $2.5 billion, 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 June 30, 2013, TVA had $24.7 billion of Bonds outstanding (not including noncash items of foreign currency exchange gain of $16 million and net discount on sale of Bonds of $82 million). Due to this limit on 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 (such as the ~~lease-purchase~~ transaction involving the John Sevier CCF), 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.

4544

Table of Contents

Debt Securities. TVA’s Bonds consist of power bonds and discount notes. Power bonds have maturities of between one and 50 years, and 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. TVA’s Bonds are not obligations of the United States, and the United States does not guarantee the payments of principal or interest on Bonds. In addition to power bonds and discount notes, TVA had outstanding at ~~March 31,~~June 30, 2013, the long-term debt of two variable interest entities. See Lease/Leaseback Financing below and Note 11 — Debt Securities Activity for additional information.

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

																																					Short-Term Borrowing Table
	At March 31 2013			Three Months Ended March 31 2013			Six Months Ended March 31 2013			At March 31 2012			Three Months Ended March 31 2012			Six Months Ended March 31 2012			At June 30 2013			Three Months Ended June 30 2013			Nine Months Ended June 30 2013			At June 30 2012			Three Months Ended June 30 2012			Nine Months Ended June 30 2012
Amount Outstanding (at End of Period) or Average Amount Outstanding (During Period)
Discount Notes	$	2,045		$	1,098		$	1,239		$	—		$	262		$	353		$	2,395		$	2,181		$	1,553		$	2,530		$	2,093		$	931
Weighted Average Interest Rate
Discount Notes	0.090		%	0.085		%	0.104		%	0.000		%	0.002		%	0.001		%	0.071		%	0.082		%	0.094		%	0.091		%	0.084		%	0.063		%
Maximum Month-End Amount Outstanding (During Period)
Discount Notes	N/A			$	2,045		$	2,045		N/A			$	785		$	785		N/A			$	2,395		$	2,395		N/A			$	2,550		$	2,550

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 11 — Credit Facility Agreements and Note 13 — Other Derivative Instruments — Collateral.


Summary of Long-Term Credit Facilities At March 31, 2013 (in billions)
Summary of Long-Term Credit Facilities At June 30, 2013 (in billions)									Summary of Long-Term Credit Facilities At June 30, 2013 (in billions)
Maturity Date	Facility Limit		Letters of Credit Outstanding		Cash Borrowings		Availability		Facility Limit		Letters of Credit Outstanding		Cash Borrowings		Availability
June 2017	$	1.0	$	0.5	$	—	$	0.5	$	1.0	$	0.4	$	—	$	0.6
December 2017	1.0		0.1		—		0.9		1.0		0.1		—		0.9
January 2014*	0.5		0.5		—		—
April 2018									0.5		0.5		—		—
	$	2.5	$	1.1	$	—	$	1.4	$	2.5	$	1.0	$	—	$	1.5

* On April 5, 2013,

Although TVA Bonds are not obligations of the United States, TVA, as a ~~$0.5 billion revolving~~corporate agency and instrumentality of the United States government, may be impacted if the sovereign credit ~~facility that matures in April 2018, replaced~~ratings of the ~~January 2014 credit facility.~~

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. ~~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~~

~~Table of Contents~~

~~of the United States are downgraded.~~ 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

Table of Contents

States from negative to stable, citing receding fiscal risks, and subsequently changed the outlook on TVA from negative to stable.

Lease/Leaseback Financing. On January 17, 2012, TVA entered into a $1.0 billion lease financing arrangement with John Sevier Combined Cycle Generation LLC ("JSCCG") for the completion and lease of John Sevier CCF. As part of the arrangement, JSCCG issued $900 million of secured notes and $100 million of membership interests subject to mandatory redemption. The membership interests in JSCCG were funded by John Sevier Holdco LLC ("Holdco") with proceeds from a $100 million secured notes issuance. TVA received approximately $970 million from the transaction, and used the proceeds to meet its requirements under the TVA Act. JSCCG deposited approximately $30 million with a lease indenture trustee to fund the first payments due on its secured notes and membership interests in July 2012. TVA has determined that JSCCG and Holdco are variable interest entities of which TVA is the primary beneficiary and, as such, TVA is required to account for the entities on a consolidated basis. See Note 7.

Seven States Power Corporation ("Seven States"), through its subsidiary, Seven States Southaven, LLC ("SSSL"), exercised its option to purchase from TVA an undivided 90 percent interest in a combined-cycle combustion turbine facility in Southaven, Mississippi. As part of interim joint-ownership arrangements, Seven States has the right at any time during the interim period, and for any reason, to require TVA to buy back SSSL's interest in the facility. The interim period under the joint-ownership arrangements was to expire on April 23, 2013. On April 18, 2013, TVA and Seven States, through SSSL, agreed to extend the expiration date of the interim joint ownership arrangements to September 5, 2013. The other material terms and conditions of the arrangements were not changed and remain in full force and effect. TVA intends to re-acquire SSSL's interest in the facility and the related assets either on or prior to the extended expiration date of September 5, 2013. The carrying amount of the Southaven obligation on TVA's consolidated balance sheets was approximately $~~370~~365 million at ~~March 31,~~June 30, 2013, and $378 million at September 30, 2012. On ~~March 31,~~June 30, 2013, this obligation was recorded in Current portion of leaseback obligations on the Consolidated Balance Sheets.

TVA may seek to enter into similar arrangements for other assets in the future, potentially including assets under construction. While such leasing transactions allow TVA to diversify its asset financing program, financing an asset by using the proceeds of leasing transactions is typically more costly to TVA than financing an asset with the proceeds of Bonds.

Summary Cash Flows

A major source of TVA's liquidity is operating cash flows resulting from the generation and sales of electricity. A summary of cash flow components for the ~~six~~nine months ended ~~March 31,~~June 30, 2013, and 2012, follows:


Summary Cash Flows	Summary Cash Flows						Summary Cash Flows
	Six Months Ended March 31						Nine Months Ended June 30
	2013			2012			2013			2012
Cash provided by (used in):
Operating activities	$	1,148		$	867		$	1,478		$	1,252
Investing activities	(1,204		)	(1,359		)	(1,745		)	(1,867		)
Financing activities	107			356			379			355
Net increase (decrease) in cash and cash equivalents	$	51		$	(136	)	$	112		$	(260	)

Operating Activities. Net cash flows provided by operating activities increased ~~$281~~$226 million for the ~~six~~nine months ended ~~March 31,~~June 30, 2013 as compared to the same period ~~during~~in the prior ~~year. The increase was~~year, primarily due to ~~an increase~~a decrease in operating ~~income~~costs from TVA's efforts to improve cost management, working capital, and operational performance. These efforts, coupled with the increased use of hydroelectric generation as a result of ~~more heating degree days during~~increases in rainfall and runoff, the ~~six months ended March 31, 2013, as compared to the same period during the prior year. See~~ ~~Results~~use of ~~Operations~~.

Furthermore, there was an increase in cash flows in the current year related to working capital activities, including a $367 million increase in changes in Inventories and other current assets, driven by increased nuclear outages and a change in gas market prices. Rising gas prices and nuclear unavailability resulted in coal-fired generation being the most economical source of power. As a result, existing coal inventories that had been built up during the prior year, ~~were used. Additionally,~~and the rising market prices of natural gas ~~decreased~~decreasing TVA's required posting of collateral cash associated with commodity ~~hedges.~~hedges, increased TVA's operating cash flows for the nine months ended June 30, 2013. See Results of Operations.

These changes in Inventories and other current assets were partially offset by a $160 million decrease in the change in Accounts receivable due to the timing of sales related to the seasonality of TVA's operations whereby sales were significantly higher during the summer months in 2011 compared to the summer months in 2012. As a result, the beginning accounts receivable balance at 2012 compared to the beginning balance at 2013 was higher.

~~Table of Contents~~

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. Net cash flows used in investing activities decreased ~~$155~~$122 million for the ~~six~~nine months ended ~~March 31,~~June 30, 2013, as compared to the same period in the prior year. This change was primarily due to the timing and prioritization of capital projects.

Financing Activities. Net cash flows provided by financing activities ~~decreased $249~~increased $24 million in the ~~six~~nine months ended ~~March 31,~~June 30, 2013, as compared to the same period in the prior year, due ~~primarily~~ to a $1.3 billion increase in redemptions of long-term debt during the six months ended March 31, 2013, as compared to same period in the prior year. The large increase in redemptions was primarily due to the $1.4 billion maturity of TVA 1998 Series C Global Power Bonds during the six months ended March 31, 2013, while only $125 million of long-term debt was redeemed in the same period in the prior year. The increase in long-term debt redemptions was offset by a $1.0 billion net change in short-term debt issuances during the six months ended March 31, 2013, as compared to the same period in the prior year. Short-term debt increased in the six months ended March 31, 2013, due to TVA’sTVA's election to maintain higher cash balances during

Table of Contents

the ~~six~~nine months ended ~~March 31,~~June 30, 2013 ~~and the replacement~~in anticipation of ~~some~~upcoming scheduled maturities of long-term debt ~~with short-term debt.~~and project financing needs.

Cash Requirements and Contractual Obligations

The estimated cash requirements and contractual obligations for TVA as of ~~March 31,~~June 30, 2013, are detailed in the following table.


Commitments and Contingencies Payments due in the year ending September 30	Commitments and Contingencies Payments due in the year ending September 30														Commitments and Contingencies Payments due in the year ending September 30
	2013⁽¹⁾		2014		2015		2016		2017		Thereafter		Total		2013⁽¹⁾		2014		2015		2016		2017		Thereafter		Total
Debt⁽²⁾	$	3,283	$	32	$	1,032	$	32	$	1,555	$	18,411	$	24,345	$	3,335	$	32	$	1,032	$	32	$	1,555	$	18,693	$	24,679
Interest payments relating to debt	632		1,179		1,177		1,132		1,119		18,998		24,237		235		1,189		1,188		1,143		1,129		19,119		24,003
Debt of VIEs	6		13		14		15		16		924		988		6		13		14		15		16		924		988
Interest payments relating to debt of VIEs	24		48		47		46		46		716		927		24		48		47		46		46		716		927
Lease obligations
Capital	1		2		2		2		2		22		31		1		4		4		4		4		35		52
Non-cancelable operating	30		38		26		25		25		113		257		11		36		30		29		28		113		247
Purchase obligations
Power	106		205		208		220		217		3,650		4,606		60		213		204		220		227		3,564		4,488
Fuel	746		1,202		1,011		682		368		2,468		6,477		110		419		479		389		319		2,962		4,678
Other	172		198		143		134		133		1,193		1,973		522		1,038		694		461		197		421		3,333
Environmental Agreements	49		75		79		66		46		9		324		50		82		73		62		46		11		324
Nuclear Power															—		11		36		1		—		—		48
Litigation settlements	6		8		1		—		—		—		15		6		8		1		—		—		—		15
Environmental cleanup costs-Kingston ash spill	74		104		39		—		—		—		217		32		104		51		—		—		—		187
Payments on other financings	406		100		104		104		104		505		1,323		381		100		104		104		104		505		1,298
Payments to U.S. Treasury
Return of Power Program Appropriation Investment	20		10		—		—		—		—		30		20		10		—		—		—		—		30
Return on Power Program Appropriation Investment	6		8		8		8		8		101		139		6		8		8		8		8		101		139
Total	$	5,561	$	3,222	$	3,891	$	2,466	$	3,639	$	47,110	$	65,889	$	4,799	$	3,315	$	3,965	$	2,514	$	3,679	$	47,164	$	65,436

Notes

(1) Period ~~April~~July 1 – September 30, 2013

(2) Does not include noncash items of foreign currency exchange gain of $16 million and net discount on sale of Bonds of ~~$83 million.~~$82 million.

~~Table of Contents~~

In addition to the obligations above, TVA has energy prepayment obligations in the form of revenue discounts.


Energy Prepayment Obligations Payments due in the year ending September 30	Energy Prepayment Obligations Payments due in the year ending September 30														Energy Prepayment Obligations Payments due in the year ending September 30
	2013⁽¹⁾		2014		2015		2016		2017		Thereafter		Total		2013⁽¹⁾		2014		2015		2016		2017		Thereafter		Total
Energy Prepayment Obligations	$	50	$	100	$	100	$	100	$	100	$	110	$	560	$	25	$	100	$	100	$	100	$	100	$	110	$	535

Note

(1) Period ~~April~~July 1 – September 30, 2013

EnergyRight^® Solutions Program. TVA guarantees repayment on certain loans receivable from customers of TVA's distributors in association with the EnergyRight^® Solutions program. TVA sells the loans receivable to a third-party bank and has agreed with the bank to purchase any loan receivable that has been in default for 180 days or more or that TVA has determined is uncollectible. At ~~March 31,~~June 30, 2013, the carrying amount of the loans receivable, net of discount, was approximately $~~151~~149 million. Such amounts are not reflected in the Commitments and Contingencies table above. The carrying amount of the associated obligation to purchase those loans was approximately $~~186~~184 million.

Table of Contents

Liquidity Challenges Related to Generation Resources

Nuclear Regulatory Commission Safety Improvements Orders and Other Guidance. On March 9, 2012, the NRC issued three new safety orders stemming from lessons learned from the events that occurred in 2011 at the Fukushima Daiichi Nuclear Power Plant ("Fukushima events"). The orders include the development of strategies for responding to an interruption of off-site power, the addition of more reliable instruments to measure water levels in cooling pools where spent nuclear fuel is stored, and the installation of more robust containment venting systems to prevent containment failure due to over-pressurization. The orders dealing with the loss of off-site power and monitoring spent fuel pools will apply to every nuclear reactor in the U.S., including Watts Bar Unit 2, which will be required to comply prior to issuance of its operating license. The order requiring more robust containment venting systems applies only to certain U.S. boiling water reactors, including Browns Ferry; these reactors are required to improve their containment venting systems to prevent over-pressurization due to the build-up of non-condensable gases such as hydrogen. Licensees have until December 2016 or until the second refueling outage after submittal of implementation plans (TVA's plans were submitted on February 28, 2013), whichever is earlier, to fully implement the requirements of these three orders. TVA's implementation of the requirements of the orders will vary from plant to plant due to the timing of the scheduled refueling outages at each plant. The cost to comply with these orders is estimated to exceed $200 million.

In addition to these orders, the NRC issued requests for information from U.S. nuclear operators regarding earthquake and flood risks and emergency planning. Based on the information provided in response to these requests, the NRC will determine if additional regulatory requirements are needed for these subjects. At this time TVA is not able to predict the final outcome of these potential requirements or the associated costs; however, these amounts could be significant. The orders and requests for information represent the Tier 1 issues associated with Fukushima. There are additional issues in Tiers 2 and 3 that may prompt future regulatory action.

Since the Fukushima events, the NRC has also issued additional detailed guidance on the expected response capability to be developed by each nuclear plant site. The Nuclear Energy Institute ("NEI") has also provided guidance that has been adopted by the NRC. TVA has developed plans and schedules for the development and implementation of strategies and physical plant modifications to address the actions outlined in the NRC orders and subsequent NRC and NEI guidance for its plants, which are being incorporated into the construction plans for Watts Bar Unit 2. Based on the current known scope of the Fukushima response requirements and the established TVA schedule, resolution of the identified issues is expected to be completed at Watts Bar Unit 2 by the fourth quarter of CY 2014. However, on-going studies related to flooding and seismic events may result in additional scope that may impact the overall Fukushima response schedule. These studies are expected to be concluded in CY 2013.

Browns Ferry. 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 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 is subject to substantially higher NRC oversight. A series of intensive inspections and assessments began in the fall of 2011.

As a result of challenges with the performance of a key safety system (high pressure coolant injection ("HPCI")) on Browns Ferry Unit 1, the related NRC Reactor Oversight Process Performance Indicator entered the “white” performance band. ~~As a result, the NRC conducted a satisfactory supplemental inspection regarding this finding in October 2012.~~ It is currently expected that this indicator may not exit the white band until ~~mid-CY 2013.~~the last half of CY 2014.

~~Additionally, because~~In addition, as a result of ~~three unplanned reactor shutdowns at Browns Ferry~~performance challenges with the emergency AC power system on Unit ~~3 at~~1 and Unit 2, the ~~end of the spring 2012 refueling outage, the related~~associated NRC Reactor Oversight Process Performance Indicators for both units entered the "white" (low to moderate safety significance) performance band. ~~The~~As a result, the NRC ~~inspected TVA's corrective actions for~~is expected to conduct an additional supplemental inspection to address this ~~issue in November 2012. The NRC issued an inspection report on~~

~~Table of Contents~~

~~November 30, 2012 and concluded that TVA had adequately completed a root cause analysis of~~issue. These indicators are not expected to exit the ~~issue and had identified appropriate corrective actions to prevent recurrence of the issue.~~white band until mid-CY 2014.

In June 2012, TVA presented its plans to improve Browns Ferry's overall performance and reduce plant risk at a public meeting with the NRC. TVA described its plans to implement corrective actions and monitor the improvement of plant performance to support the NRC's supplemental inspections of Browns Ferry related to the 2011 red finding. TVA noted that while, at that time, much improvement remained to be realized, there were initial indications that improvement was occurring. Subsequently, in February 2013, TVA notified the NRC that Browns Ferry was ready for the NRC to conduct the significant inspection associated with the red finding (referred to as a 95003 inspection). ~~Initial aspects~~The NRC completed this inspection, conducted a public meeting on July 11, 2013, and will formally notify TVA of ~~that inspection are underway and~~ the ~~major~~results in August 2013. The NRC ~~inspection trip for the red finding is currently scheduled for May 2013.~~noted significant improvement; however, additional actions may be required as will be directed through an NRC Confirmatory Action Letter. The TVA Board has approved the expenditure of up to $138 million through 2015 to accelerate improvements in Browns Ferry's performance and reliability.

In June 2013, TVA received an Apparent Violation associated with the circumstances that resulted in the December 22, 2012, Unit 2 unplanned reactor shutdown. The NRC's final enforcement decision is pending. Depending on the results, TVA may be subject to an additional supplemental inspection.

Table of Contents

Also, because of an unplanned reactor shutdown of Browns Ferry Unit 3 during the first quarter of CY 2013, the related NRC Reactor Oversight Process performance indicator entered the "white" performance band. As a result, TVA will receive an additional supplemental inspection.

In October 2012, the Institute of Nuclear Power Operations ("INPO") Accrediting Board of the National Academy of Nuclear Training renewed accreditation for Browns Ferry’s training programs for chemistry technicians, radiation protection technicians, instrumentation and controls, and electrical and mechanical maintenance. However, the INPO Board placed the engineering training program on probation. A recovery plan was implemented and accreditation for the engineering training program was ~~reaccredited~~renewed in March 2013.

In March 2013, TVA submitted a ~~License Amendment Request~~license amendment request to the NRC requesting a change to Browns Ferry's operating license to transition to a risk-based fire protection program as defined under the fire code commonly referred to as the National Fire Protection Association Standard 805. As scoped in the license amendment request, design and modifications will be performed over the next six years. Cost estimates are still being developed ~~but~~and costs are expected to be significant.

Extreme Flooding Preparedness. Updates to the TVA analytical hydrology model have indicated that under "probable maximum flood" assumptions, some of TVA's dams would not be high enough to contain the flood waters. A "probable maximum flood” is an extremely unlikely event, and TVA is taking actions with the aim of ensuring that flood waters would pass safely and not cause failure of these dams. TVA implemented interim dam modifications in the first quarter of 2010 by installing engineered, interconnected, fabric-lined containers filled with compacted crushed stone to protect four ~~upstream~~ dams. TVA is preparing a final Environmental Impact Statement in accordance with the National Environmental Policy Act to identify permanent solutions.

As discussed above under Nuclear Regulatory Commission Safety Improvement Orders and Other Guidance, the NRC has issued requests for information from U.S. nuclear operators regarding flood risks. In response to this request, TVA is performing additional hydrological analyses. In March 2013, TVA advised the NRC that it will complete these analyses in early 2015. The results of these analyses and the NRC's response to the information could identify the need for additional modifications.

In June 2012, TVA committed to the NRC to make a series of near-term and longer-term improvements to reduce flooding concerns at Watts Bar and Sequoyah. These improvements are in addition to the interim dam modifications described above. The near-term improvements involve the construction of flood barriers around specific components or buildings at the plants. Any specific improvements will be identified after the completion of necessary technical and environmental reviews.

In March 2013, the NRC advised TVA of multiple apparent violations associated with TVA’s management of several aspects of the hydrology issues associated with Watts Bar and Sequoyah. These apparent violations ~~have been~~were discussed at a regulatory conference with the NRC in late April 2013. ~~There is potential~~In June 2013, the NRC issued the final significance determination of these apparent violations. The NRC concluded that there were two violations of the ~~resolution~~low to moderate safety significance (white) and one Severity Level III violation at Sequoyah and one violation of ~~this enforcement process could involve~~substantial safety significance (yellow), one ~~or more significant “white” or “yellow” findings for either or both~~violation of low to moderate safety significance, and one Severity Level III violation at Watts ~~Bar and Sequoyah.~~Bar. As a result, TVA will be subject to additional supplemental inspections with respect to these issues.

The total financial impact of the regulatory issues and the permanent modifications to any additional dams or plants downstream identified as a result of the assessment is being evaluated, and the evaluation should be completed by 2015. The costs associated with the potential improvements to the dams and plants are still unknown but could be significant.

Sequoyah Units 1 and 2. In June 2013, the NRC issued the final significance determination associated with a violation of security requirements. As a result, TVA will be subject to an additional supplemental inspection.

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 of Directors (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 has not identified any new short-term issues that could compromise project completion. The revision to the construction schedule estimated completion between September 2015 and June 2016, and ~~construction is currently expected~~TVA plans to ~~be completed~~bring Unit 2 into commercial operations by December 2015. ~~Regulatory and licensing issues remain as primary risks for the project.~~ The ~~risks include compliance~~NRC agreed in April 2013 with the ~~NRC requirements resulting from~~industry’s approach to address seismic issues associated with the Fukushima ~~events; resolution~~event, reducing uncertainty in TVA’s implementation of actions to resolve this issue. Progress by the ~~NRC's~~NRC in addressing Waste Confidence ~~Decision relating~~(relating to the potential environmental impacts of storage of spent fuel at each reactor ~~site; and resolution of an aquatic contention~~site) also improves the likelihood that this issue will be resolved in ~~an ongoing contested licensing proceeding.~~a timely fashion. The current construction permit expired in March 2013. An extension to the permit has been requested and by regulation, work is allowed to proceed. An extended permit is expected in the summer of 2013.

Bellefonte Unit 1. ~~TVA has initiated an~~ ~~Interim Estimate to Complete ("IETC")~~ ~~for~~The incorporation of Watts Bar Unit 2 lessons learned into the Bellefonte Nuclear Plant ("Bellefonte") ~~construction project. The IETC was started~~Unit 1 completion estimate has revealed some similar problems and inaccuracies. It is evident the final estimate for Bellefonte Unit 1 will rise above the current approved amount. Work continues to ~~determine how lessons learned from~~complete and validate a true estimate to complete for Bellefonte Unit 1. In the ~~Watts Bar Unit 2 Estimate~~interim, work at the site has been slowed to better allocate resources on nearer-term priorities.

5049

Table of Contents

~~to Complete might impact the Bellefonte project. The IETC does not replace the planned project Estimate to Complete; however, it will provide insight into how the project is trending in regard~~On June 12, 2013, TVA announced changes to the ~~estimate approved by the Board in 2011.~~spending and staffing levels at Bellefonte. The ~~IETC is in progress~~planned budget for 2014 and ~~current indications are~~staffing levels will both be reduced. TVA believes that the ~~cost~~budgeting and staffing levels should be sufficient to finalize the interim estimate to complete for Bellefonte Unit 1 ~~will rise.~~that is currently underway and to protect 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. TVA's update to its Integrated Resource Plan is scheduled to be completed in 2015.

2013 Key Initiatives and Challenges

Generation Resources

TVA faces potentially large capital requirements to maintain its power system infrastructure and invest in new power assets, including generation assets using cleaner energy sources.

Nuclear Generation. During the summer of 2012, Cooling Tower 3 at Browns Ferry partially collapsed and Cooling Tower 5 was inspected and subsequently condemned. Replacement towers are not expected to be available until sometime during the fourth quarter of 2013. Although the other five cooling towers at Browns Ferry should be available throughout 2013, Browns Ferry may experience some curtailment of generation due to hydrothermal issues during the summer of 2013.

On January 15, 2013, TVA submitted the license renewal application to the NRC for Sequoyah Units 1 and 2. If approved, the operating 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 may take up to three years. It is possible that the approval of the license renewal applications could be impacted by the NRC’s consideration of industry-wide issues, such as revisions to the Waste Confidence Decision, finalization of regulations in response to Fukushima events and other ~~guidance.~~ guidance, as well as the administrative proceeding opposing the renewal of the operating license. See Note 17—Administrative Proceeding Regarding Renewal of Operating License for Sequoyah Nuclear Plant.

Coal-Fired Units. In April 2011, TVA entered into two substantively similar agreements, one with the Environmental Protection Agency ("EPA") and the other with Alabama, Kentucky, North Carolina, Tennessee, and three environmental advocacy groups (collectively, the "Environmental Agreements”). See Note 17 — 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. The remaining two units at John Sevier were idled on December 31, 2012.

On December 21, 2012, ~~in accordance with the requirements in the Environmental Agreements,~~ TVA notified the EPA of its decision regarding options for Units 3 and 4 at John Sevier and Unit 5 at Colbert Fossil Plant ("Colbert"). TVA elected to retire John Sevier Units 3 and 4 by December 31, 2015 and to remove Colbert Unit 5 from service effective December 31, 2015. Additionally, TVA provided notice that it will locate a Particulate Matter Continuous Emissions Monitor ("PM CEM") on the common stack for Shawnee Fossil Plant Units 6-10 in lieu of installing the PM CEM at Colbert Unit 5. On June 28, 2013, in accordance with the requirements in the Environmental Agreements, TVA notified the EPA of its decision regarding Units 1-4 at Colbert, electing the “Remove from Service” option for these units effective June 30, 2016. With respect to Widows Creek Fossil Plant Units 1-6, TVA must retire two units by July 31, 2013, two additional units by July 31, 2014, and the remaining two units by July 31, 2015. TVA, in accordance with the requirements of the Environmental Agreements, has selected Units 3 and 5 for retirement effective July 31, 2013.

On July 15, 2013, TVA determined that Colbert Unit 5 will be idled on October 1, 2013. Colbert Unit 5 had been scheduled to idle on October 1, 2014. It is expected that the decision to idle Colbert Unit 5 on October 1, 2013 will increase depreciation expense by approximately $14 million during the fourth quarter of 2013 due to the acceleration of the idling date.

In March 2013, TVA announced it is proceeding with a $1.1 billion emissions control project at Gallatin Fossil ~~Plant ("Gallatin")~~.Plant. The project includes the installation of selective catalytic reduction ("SCR") systems and scrubbers at all four units of the 976 MW plant. The scrubbers are expected to be completed in 2016, with the SCR systems to follow in 2018.

Due to the age, lower capacity, and lower efficiency of TVA's older coal-fired units, it may not be economical to continue to operate some units in the future, particularly if new environmental laws or regulations become effective. However, discontinuing the use of some coal-fired units may be constrained by transmission reinforcement that will be required before the units are taken out of service.

TVA is also planning to convert its wet ~~CCR~~coal combustion residual facilities to dry collection ~~facilities, and the~~facilities. The estimated cost of this conversion is between $1.5 billion and $2.0 billion. The current schedule for completion is December 2022.

Combined-Cycle Combustion Turbine Units. In March 2013 TVA experienced a generator failure and subsequent forced outage on at John Sevier Combined Cycle Plant ~~("John Sevier CC")~~Unit 1. ~~It is anticipated that repairs will be completed by mid-summer of 2013.~~ Because of this failure, Units 2 and 3 were inspected to determine their risk of failure and both units ~~will require~~required repairs ~~as well~~ to prevent a similar failure. These two units ~~have also been placed~~were returned to service in ~~forced outages~~June 2013 and ~~it is likely these units will be unavailable most of~~ the third ~~quarter of~~unit is expected to be returned to service in September 2013.

~~John Sevier CC, with a net summer capability of 870 MW, was added to the TVA generating fleet in 2012. Although the~~ The cost of repairs iswas covered under the construction/purchase warranty, the extent of these outages will likely result in TVA having to purchase higher cost power for some portion of the summer and pose a potential risk that TVA would not be able to support transmission minimum requirements in this region. warranty.

Status of Other Generation Units. TVA had several hydroelectric and combustion turbine units removed from service as of ~~March 31,~~June 30, 2013.

Table of Contents

Inspections of the turbines in the four units of the Raccoon Mountain Pumped-Storage Plant ("Raccoon Mountain") during 2012 found cracking in the rotor poles and the rotor rims. Because the same type of cracking led to the catastrophic failure of a similar unit in Europe, the Raccoon Mountain units were taken out of service. ~~The units, with a net summer capability of~~ ~~1,616~~ ~~MW, are utilized to balance the transmission system as well as generate power.~~ Raccoon Mountain Unit 2 returned to limited service with a partially restacked rotor in October 2012, but was taken out of service again on January 3, 2013, due to a failed rotor pole clamp. ~~The unit has been disassembled, and a root cause analysis is being conducted.~~ All units are undergoing a maintenance overhaul, and are expected

~~Table of Contents~~

to be returned to service with new rotors in the 2013-2014 timeframe. TVA is dispatching generation from other TVA units and purchasing power if needed to compensate for the loss in generating capacity.

Effective May 1, 2012, four simple-cycle combustion turbine units at TVA’s Allen Fossil Plant ("Allen"), with a total net summer capability of 64 MW, were designated as temporarily unavailable for operation until repairs have been performed. Restoration projects to return the Allen units to active service are being planned for the fall of 2013 through the spring of 2014. Two simple cycle-combustion turbine units at Gallatin, with a total net summer capability of 144 MW, previously listed as unavailable for operation, were restored to full capability and availability in the second quarter of 2013.

Transmission Issues. Since announcement of the proposed integration of Entergy Corporation ("Entergy") into the ~~Midwest~~Midcontinent Independent Transmission System Operator, Inc. ("MISO") market, TVA has been evaluating potential impacts to the reliability of its transmission system. TVA completed a detailed reliability assessment during the second quarter of 2013 which identified that significant transmission reinforcements will be required if new coordinated planning and operational processes are not implemented. ~~Evaluations~~Proposals to mitigate effects on TVA and others are being discussed with MISO.

As a result of these discussions, TVA and neighboring utilities reached a transition agreement with MISO on June 19, 2013 to limit market dispatch flows between its existing region and its new members including Entergy, Louisiana Generating, LLC, South Mississippi Electric Power Association and others collectively referred to as the MISO South Region. The transition agreement limits power transfers between the regions and requires MISO to respect TVA flowgate limits in real-time. The transition agreement reduces the impact of these transfers on TVA and the other affected parties through April 2015 with the intent to incorporate the use of tools and processes developed in the transition period into operations agreements thereafter.

Capacity Agreement. On December 27, 2012, TVA signed a 10-year conversion services agreement with Calpine Energy Services, L.P., that gives TVA exclusive rights to the Decatur Energy Center in Decatur, Alabama, a 720 MW summer capacity, natural gas-fired combined cycle plant. Under this conversion services agreement, TVA will deliver natural gas to the plant and the plant, which is owned and operated by affiliates of Calpine Energy Services, L.P., will convert the natural gas to electricity and deliver the power to TVA's transmission system. The contract became effective January 1, 2013.

Regulatory Compliance

Commercial Grade Part Dedication Issues. ~~In March~~The NRC issued TVA a Severity Level III violation on June 18, 2013 ~~TVA conducted a public meeting~~for issues with the ~~NRC~~commercial grade dedication ("CGD") process at Watts Bar Unit 2. Commercial Grade Dedication refers to ~~address concerns regarding TVA’s~~ practices for procuring certain ~~parts for installation in its nuclear plants. The practice under question by the NRC involves~~ parts that are obtained from general commercial suppliers and subsequently evaluated ~~by TVA~~ for acceptability for use in nuclear plants. ~~This practice, which is permitted by~~The subject of the violation involved a breakdown of the quality assurance program in the CGD area, a failure to report that breakdown, and the failure to identify a significant condition affecting quality. TVA accepted the violation and responded to the NRC ~~regulations, requires certain controls and documentation. At~~in July 2013, outlining correction actions to be taken to ensure compliance in the meeting, TVA indicated that its practices for dedicating commercially obtained parts had not met some regulatory requirements from 1995 to 2011. TVA outlined a recovery project to review the documentation, and if necessary, to test commercially obtained and dedicated parts installed in its nuclear plants.future.

Kingston Fossil Plant. In December 2008, a dike around one of the dredge cells at the Kingston Fossil Plant failed, ~~and~~releasing approximately ~~five~~5.4 million cubic yards of ~~water~~coal ash. Approximately 3.0 million cubic yards of ash were recovered from the adjacent Emory River in 2009 and ~~coal fly ash flowed out~~2010. It was transported offsite for disposal. In June 2013, TVA finished recovering approximately 2.4 million cubic yards 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~~adjacent Swan Pond Embayment, and is currently placing that ash in an onsite ash landfill. Once the ~~third quarter of 2010, and removal~~ash is stacked in place, the ash landfill will be closed by constructing a multi-layer cap over the ash. In June 2013, TVA began placing the first section of the ~~remaining ash~~multi-layer cap. The final cap is ~~considered~~forecasted to be ~~non-time-critical. In November 2012,~~completed by early 2015. A perimeter wall is also being constructed to stabilize the ~~EPA~~perimeter of the landfill to contain the ash. The wall construction is expected to be completed by mid-August 2013, with some grouting of repairs through the first of next year.

Long-term monitoring of the Emory River was initiated in the Spring of 2013 and will continue for up to 30 years. Results of this monitoring will be used to evaluate the ecological resources in the river system and the ~~Tennessee Department of Environment and Conservation ("TDEC")~~ ~~approved a plan to allow the Emory River's~~river’s natural processes ~~to remediate the remaining~~for remediating any residual ash in the ~~river,~~river. In addition, TVA is restoring the ecological habitat along the Emory River and ~~to conduct a long-term monitoring program. TVA estimates that the physical cleanup work (final removal) will be completed~~ in the ~~first quarter of~~Swan Pond Embayment. That work is scheduled to begin later this year, and is expected to be finished by Spring 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. See Note 8.

~~Blue Ridge Dam~~Adjustment to Nuclear Insurance Costs. The Price-Anderson Act provides a layered framework of protection to compensate for losses arising from a nuclear event in the United States. In addition to requiring all NRC nuclear plant licensees to purchase nuclear liability insurance, the Price-Anderson Act requires licensees to pay a specified total amount per unit for any nuclear event, including events at other licensees’ facilities, plus a five percent surcharge. The NRC adjusts this amount every five years to account for inflation. On July 12, 2013, the NRC increased this total amount (per unit and ~~Other~~ for each event) to $127 million per unit, effective September 10, 2013. The maximum amount that could be recovered per year per unit is $19 million. The prior amounts were a total assessment of $118 million per unit with a maximum annual payment of $18 million per unit.

Table of Contents

Dam Safety ~~Improvement~~Assurance Initiatives

TVA has an established dam safety program, which includes procedures based on the Federal Guidelines for Dam Safety. One aspect of the guidelines is that dam structures will be periodically reassessed to assure that TVA's dams meet current design criteria. TVA is currently performing reassessments of its assets; these assessments or health checks include material sampling of the dam and foundational structures and detailed engineering analysis. It is expected that projects will be identified during these health checks and the work will be appropriately prioritized and completed within TVA’s capital improvement process. Current dam upgrade projects already underway include raising the dam height at Cherokee, Watts Bar, Tellico, and Fort Loudon to meet current predicted probable maximum flood heights, and installation of post tension anchors at Cherokee and Douglas dams to improve stability.

TVA initiated a rehabilitation project on the Blue Ridge Dam in 2009. Work to repair and stabilize the downstream side of the dam was nearly complete when, on February 29, 2012, monitoring surveys indicated some down slope movement. Subsequent increased surveillance and monitoring ~~indicated~~indicates that ~~settlement and down slope movement continued but remained within safety tolerances. At this time,~~ movement of the embankment has stopped.

~~Based on TVA’s continuous monitoring and analysis, TVA considers the dam safe at this time.~~ Additional engineering analyses to determine the cause of the movement have been completed. TVA ~~has~~ determined that the static stability of the dam should be increased for normal ~~operations. Remediation is underway~~operations and ~~should be~~remediation was completed in July 2013. The analysis to bring the dam up to current industry standards for seismic qualifications remains to be completed. ~~In addition, other dams within the TVA system are being evaluated to confirm their integrity. There may or may not be any modifications necessary as a result of these additional analyses.~~

Future Workforce Needs and Development

Although TVA has traditionally experienced low employee turnover, potential future risks exist because of retirements and competition for talent among utility companies. Personnel with nuclear expertise, skills related to construction and installation of new environmental controls, and experience with energy efficiency and demand response initiatives are limited. To ensure that TVA can continue to attract and retain a skilled workforce needed to achieve its vision, TVA revised and implemented an agency wide workforce planning program in 2012.

On March 26, 2013, legislation that extends the federal pay freeze through December 31, 2013 became law. TVA officers continue to be subject to this freeze, and TVA will continue compliance with the freeze for managers, specialists, and

~~Table of Contents~~

excluded employees for the remainder of the calendar year. The federal salary freeze does not apply to TVA's represented employees, whose salary increases are governed by the terms of collective bargaining agreements, certain promotions and changes in positions, and other forms of non-salary compensation such as lump-sum and incentive-based awards.

Other Initiatives

Nuclear. In November 2012, the Department of Energy ("DOE") announced a grant award to Babcock & Wilcox ("B&W"), in conjunction with TVA and Bechtel, for small modular reactor ("SMR") development. TVA and B&W subsequently signed a contract in February 2013 establishing the process toward submittal and the NRC review of a license application. The B&W designed SMR would have a scalable, modular design allowing utilities to add electrical generation capacity in increments of 360 MW. The proposed site for the reactor is TVA’s Clinch River site near the DOE’s Oak Ridge, Tennessee reservation. DOE will invest up to half of the total cost for design, certification, and licensing with the project's industry partners (including TVA) matching this investment by at least one-to-one. ~~The specific total cost will be negotiated between DOE and B&W.~~

TVA has been evaluating SMRs since 2009 but SMRs are still in the early phase of design and licensing. TVA is preparing the license application, including site characterization work, and the application should be submitted to the NRC in 2015. The Clinch River project will be evaluated at certain progress points to permit TVA to determine whether to continue the development or construction of the project.

Customers/Counterparties Risk

United States Enrichment ~~Corporation.~~ Corporation. In May 2012, TVA extended its power contract with its largest directly served customer, United States Enrichment Corporation ("USEC"), a subsidiary of USEC, Inc. ~~Power~~On May 24, 2013, USEC announced the cessation of enrichment activities at their Paducah site. TVA and USEC have subsequently completed agreements to extend power sales ~~under~~to facilitate the ~~contract are scheduled~~cessation of enrichment activities and to support non-enrichment activities at the site for June and July at a greatly reduced level. These sales arrangements may continue ~~through May 31, 2013.~~to be extended. Power sales to USEC represented five percent and four percent of TVA's total operating revenues for the years ended September 30, 2012, and 2011, respectively. See Note 13 — Counterparty Credit Risk.

The TVA-USEC power contract provided TVA with interconnection to critical electrical facilities operated and maintained by USEC, and has recently been amended so TVA’s interconnection rights will continue until USEC's lease terminates and control of the facilities is returned to DOE, presently anticipated to occur around the second quarter of 2014. TVA has initiated discussions with DOE concerning TVA’s continued use of the facilities following termination of the USEC lease.

USEC is also a supplier of enrichment services for uranium for fueling TVA's nuclear units through November 2014. USEC is, among others, a participant in a high assay tails (depleted uranium hexafluoride) enrichment program. This tails enrichment program ~~may allow~~allowed USEC to extend its enrichment operations through May 31, 2013. In May 2012, TVA contracted

Table of Contents

with Energy Northwest, a participant in the program, to buy a substantial portion of the program's output in the form of enrichment services and uranium hexafluoride. Should USEC fail to provide enrichment services, TVA has sufficient nuclear fuel inventory available to mitigate near-term supply risks, and also expects to be able to procure material at reasonable rates in the market for nuclear fuel.

Environmental Matters

TVA's power generation activities are subject to most federal, state, and local environmental laws and regulations. Major areas of regulation affecting TVA's activities include clean air 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 and to apply to additional emissions and sources. Emissions from all TVA-owned and operated units (including small combustion turbine units of less than 25MW that are not required to be reported to the EPA) have been reduced from historically high peaks. Emissions of NO_x have been reduced by 90 percent below peak 1995 levels and emissions of SO₂ have been reduced by 94 percent below 1977 levels through CY 2012.

NAAQS for Particulate Matter

On December 14, 2012, the EPA issued the final rule for the National Ambient Air Quality Standards ("NAAQS") for particulate matter ("PM"), lowering the annual PM 2.5 (fine particulate) standard from 15 to 12 micrograms per cubic meter. The daily PM 2.5 standard and the daily PM 10 (coarse particulate) standard remain at 35 and 150 micrograms per cubic meter, respectively. The EPA is expected to issue yet another revision to the PM standards in the CY 2017-2018 timeframe.

The new standard results in additional requirements on many sources. The EPA is expected to make final designations of non-attainment areas in 2014. The new, more stringent PM 2.5 standard is expected to be addressed in the rule which the EPA is currently developing to replace the Cross State Air Pollution Rule ("CSAPR"), which was vacated by the U.S. Court of Appeals for the D.C. Circuit in August 2012. Additional requirements beyond CSAPR revisions are unknown at this time.

Draft Effluent Limit Guidelines

The EPA's draft effluent limit guidelines for steam electric power generating facilities were published in June 2013. The guidelines set forth a number of control alternatives, most of which would result in additional, substantial water pollution control costs at TVA coal-fired plants.

Climate Action Plan

On June 25, 2013, the President released his Climate Action Plan which includes a broad range of executive actions to mitigate U.S. carbon emissions, manage climate change adaptation efforts and lead international efforts. Included is a memorandum from the President to the EPA directing the EPA to issue a new proposal for carbon pollution standards for future power plants by September 20, 2013 and proposed carbon pollution standards for existing power plants by June 1, 2014. The standards for future power plants are to be finalized after the EPA considers all public comments, and the standards for existing power plants are to be finalized by June 1, 2015. The President's plan does not contain sufficient detail to determine how TVA may be impacted, but TVA's ongoing and planned activities are consistent with the plan.

Federal agencies currently have renewable energy consumption goals which originated in the Energy Policy Act of 2005 of three percent renewable energy consumption by 2007, five percent by 2010, and seven and one-half percent by 2013 and beyond. TVA's 2012 performance was nearly eight percent, exceeding the 2013 goal. The President's Climate Action Plan establishes a new goal of 20 percent of internally used electricity from renewable sources by 2020. At this time, the President's plan does not contain sufficient detail to determine how TVA may be impacted.

Table of Contents

Estimated Required Environmental Expenditures

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


Air, Water, and Waste Quality Estimated Potential Environmental Expenditures⁽¹⁾ At March 31, 2013 (in millions)
Air, Water, and Waste Quality Estimated Potential Environmental Expenditures⁽¹⁾ At June 30, 2013 (in millions)				Air, Water, and Waste Quality Estimated Potential Environmental Expenditures⁽¹⁾ At June 30, 2013 (in millions)
	Estimated Timetable	Total Estimated Expenditures		Estimated Timetable	Total Estimated Expenditures

Site environmental remediation costs⁽²⁾	2013+	$	12	2013+	$	12
Coal combustion residual conversion and remediation⁽³⁾	2013-2023	$	1,400	2013-2023	$	1,400
Proposed clean air projects⁽⁴⁾	2013-2022	$	2,200	2013-2022	$	2,200
Clean Water Act requirements⁽⁵⁾	2013-2020	$	1,200	2013-2022	$	1,200

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).

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 $~~340~~319 million with respect to Legal Proceedings as of ~~March 31,~~June 30, 2013. 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 17, which discussion is incorporated into this Part I, Item 2, Management's Discussion and Analysis of Financial Condition and Results of Operations.

Off-Balance Sheet Arrangements

At ~~March 31,~~June 30, 2013, TVA had no off-balance sheet arrangements.

Critical Accounting Policies and Estimates

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

New Accounting Standards and Interpretations

For a discussion of TVA’s new accounting standards and interpretations, see Note 2, which discussion is incorporated into this Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Corporate Governance

On ~~February 19,~~July 8, 2013, ~~Kimberly S. Greene, TVA's~~Preston D. Swafford, TVA’s Executive Vice President and Chief ~~Generation~~Nuclear Officer, announced ~~she~~that he would be resigning from TVA, with an effective ~~March 31,~~date no later than October 4, 2013.

On March 14, 2013, Charles Pardee signed an agreement with TVA accepting an offer for the position of TVA's Executive Vice President and Chief Generation Officer. He began his employment with TVA on April 8, 2013.

Table of Contents

On July 9, 2013, TVA announced the appointment of Joseph P. “Joe” Grimes, Jr., as TVA’s Executive Vice President and Chief Nuclear Officer. He will replace Preston Swafford and report to TVA’s Executive Vice President and Chief Generation Officer. Mr. Grimes is scheduled to report to TVA no later than September 3, 2013.

Other Matters

On April 10, 2013, the Fiscal Year 2014 Budget of the U.S. Government (the “Budget”) was submitted to Congress. The Budget contains the following language regarding the TVA:

In order to meet its future capacity needs, fulfill its environmental responsibilities, and modernize its aging generation system, TVA's current capital investment plan includes more than $24.6 billion of expenditures over the next 10 years. However, TVA's anticipated capital needs are likely to quickly exceed the agency's $30.0 billion statutory cap on indebtedness. Reducing or eliminating the Federal Government's role in programs such as TVA, which have achieved their original objectives and no longer require Federal participation, can help put the Nation on a sustainable fiscal path. Given TVA's debt constraints and the impact to the Federal deficit of its increasing capital expenditures, the Administration intends to undertake a strategic review of options for addressing TVA's financial situation, including the possible divestiture of TVA, in part or as a whole.

Subsequent to April 10, 2013, TVA has been working with the Office of Management and Budget to provide the information they have requested. Even though TVA is owned by the federal government, it does not receive taxpayer dollars and its debt is not taxpayer funded.

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.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

ITEM 4. 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 ~~March 31,~~June 30, 2013. 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 ~~March 31,~~June 30, 2013, 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.

Changes in Internal Control over Financial Reporting

During the three months ended ~~March 31,~~June 30, 2013, 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.

Table of Contents

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

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

For a discussion of certain current material Legal Proceedings, see Note 17, which discussion is incorporated by reference into this Item 1, Legal Proceedings.

ITEM 1A. RISK FACTORS

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

Table of Contents

ITEM 6. EXHIBITS



Exhibit No.	Description

10.1	~~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)~~

~~10.2~~	$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~~TVA's Current Report on Form 8-K filed on April 10, 2013, File No. 000-52313)

~~10.3~~10.2	Supplement No. 5 Dated as of April 18, 2013, to the Joint Ownership Agreement Dated as of April 30, 2008, Between Seven States Power Corporation and TVA (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on April 23, 2013, File No. 000-52313)

~~10.4~~10.3	Third Amendment Dated as of April 18, 2013, to Lease Agreement Dated September 30, 2008, Between TVA and Seven States Southaven, LLC (Incorporated by reference to Exhibit 10.2 to TVA's Current Report on Form 8-K filed on April 23, 2013, File No. 000-52313)

10.4	Fourth Deferral Agreement Between TVA and John M. Thomas, III, Dated as of April 22, 2013

10.5	Third Deferral Agreement Between TVA and Ralph E. Rodgers Dated as of April 23, 2013

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

* In accordance with Rule 406T of Regulation S-T, these XBRL (eXtensible Business Reporting Language) documents are furnished and not filed for purposes of Section 18 of the Securities Exchange Act of 1934 and otherwise are not subject to liability under this section.

Table of Contents ��

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:	~~May~~August 2, 2013		TENNESSEE VALLEY AUTHORITY
			(Registrant)


		By:	/s/ William D. ~~Johnson__~~ Johnson
			William D. Johnson
			President and Chief Executive Officer (Principal Executive Officer)
		By:	/s/ John M. Thomas, III~~______________~~
			John M. Thomas, III
			Executive Vice President and Chief Financial Officer (Principal Financial Officer)

Table of Contents

EXHIBIT INDEX



Exhibit No.	Description

10.1	~~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)~~

~~10.2~~	$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~~TVA's Current Report on Form 8-K filed on April 10, 2013, File No. 000-52313)

~~10.3~~10.2	Supplement No. 5 Dated as of April 18, 2013, to the Joint Ownership Agreement Dated as of April 30, 2008, Between Seven States Power Corporation and TVA (Incorporated by reference to Exhibit 10.1 to TVA's Current Report on Form 8-K filed on April 23, 2013, File No. 000-52313)

~~10.4~~10.3	Third Amendment Dated as of April 18, 2013, to Lease Agreement Dated September 30, 2008, Between TVA and Seven States Southaven, LLC (Incorporated by reference to Exhibit 10.2 to TVA's Current Report on Form 8-K filed on April 23, 2013, File No. 000-52313)

10.4	Fourth Deferral Agreement Between TVA and John M. Thomas, III, Dated as of April 22, 2013

10.5	Third Deferral Agreement Between TVA and Ralph E. Rodgers Dated as of April 23, 2013

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