Edgar Filing: Tennessee Valley Authority

form10qa.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q/A

Amendment No. 1

(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 December 31, 2007

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	62-0474417
of Congress	(I.R.S. Employer Identification No.)
(State or other jurisdiction of incorporation or organization)

400 W. Summit Hill Drive	37902
Knoxville, Tennessee	(Zip Code)
(Address of principal executive offices)

(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 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

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Explanatory Note

In this Amendment to the Quarterly Report on Form 10-Q/A for the three months ended December 31, 2007 (“Form 10-Q/A”), the Tennessee Valley Authority (“TVA”) is restating the financial statements for the three months ended December 31, 2007, and 2006, primarily to restate revenue associated with an accounting error in the financial statements included in the original Quarterly Report on Form 10-Q for the quarterly period ended December 31, 2007 (the “Original 10-Q”). The error was discovered during TVA’s review of its unbilled revenue estimation process.

TVA is primarily a wholesale provider of power to distributor customers (“distributors”) that resell the power to end users at retail rates. Under TVA’s end-use billing arrangements with distributors, TVA relies on distributors to report their end-use sales. Because of the delay between the wholesale delivery of power to the distributor and the report of end-use sales to TVA, TVA must estimate the unbilled revenue at the end of each financial reporting period. In September 2006, TVA implemented a change in methodology for estimating unbilled revenue for electricity sales which resulted in an increase of $232 million in unbilled revenue (2.6 percent of operating revenue) for 2006.

The estimation process implemented in September 2006 utilized the distributors’ average rates and an estimate of the number of days of revenue outstanding to reflect the delay in reporting the end-use sales to TVA (“days outstanding”). The number of days outstanding was derived using a procedure similar to a cross-correlation calculation that compared the monthly retail load to the monthly wholesale load. The intent was to reflect in the unbilled estimate the end-use sales that would be reported that month by distributors plus any remaining sales that would not be reported until the following month due to the delay between wholesale delivery and end-use reporting.

TVA has determined that the process implemented in September 2006 overestimated the days outstanding and that this overestimation resulted in an error in recording unbilled revenue and unbilled receivables. The previous unbilled process also failed to consider the annual true-up of each distributor’s reported distribution losses. The annual true-up reconciles total end-use kilowatt-hour (“kWh”) sales and revenue reported by each distributor with the kWh sales recorded for each distributor at wholesale.

TVA has used a new process for estimating unbilled revenue for the three months ended December 31, 2007, and 2006 in this Form 10-Q/A. This process carries over only the portion of sales from the distributor’s meter read date to the month-end. Those sales, along with the current month sales, are then priced at rates based on each distributor’s customer and product mix. Additionally, the true-up component has been added to the unbilled calculation to reflect any timing differences that occur between the retail and wholesale billing cycles. Due to the new process, an adjustment was made to increase revenue for the three months ended December 31, 2007, by $8 million (less than one percent of quarterly operating revenues) and to increase revenue for the three months ended December 31, 2006, by $21 million (approximately one percent of quarterly operating revenues).

The restatement of unbilled revenue also affected TVA’s fuel cost adjustment (“FCA”) calculation. The FCA is a mechanism by which TVA collects the direct cost of fuel used in its generating facilities and also the energy costs of purchased power used to serve power demand. Implementation of the FCA occurred in October 2006 as a joint effort between TVA and its customers. The goal of the FCA is timely recovery of fuel-related expenses to reduce the volatility driven by fuel and purchased power markets. Under TVA’s FCA methodology, adjustments to rates are based primarily on the difference between forecasted and actual expenses for the upcoming quarter, as well as the difference between forecasted and actual revenues for the upcoming quarter. Because the FCA adjustments are forward-looking, there is typically a difference between what is collected in rates and what actual expense is realized over the course of the quarter. This difference is added to or subtracted from a deferred account on TVA’s balance sheet.

The restatement of unbilled revenue changed TVA’s forecasted revenues, and since forecasted revenues are a major component of the FCA calculation, the change in forecasted revenues required a restatement of the amounts in TVA’s deferred FCA account. In the Original 10-Q, TVA reported a FCA deferred balance of $151 million at December 31, 2007, which was restated to a deferred balance of $117 million. Of the $117 million, $15 million is a deferred asset and $102 million is a current receivable.

The unbilled revenue error also affected the application of distributor prepayments. The balance in the distributors’ unbilled accounts receivable is offset by a reduction in the advance collections of those distributors who make prepayments for their power. As a result of the change in unbilled revenue, the balances in the unbilled receivable and advance collections accounts were also adjusted. The adjustment related to distributor prepayments increased the balance in the receivable and advance collections accounts by less than $1 million as of December 31, 2007.

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In light of the need for this restatement, TVA has identified a material weakness in its internal control over financial reporting related to its unbilled revenue calculation, and has concluded that its disclosure controls and procedures were not effective as of December 31, 2007, solely because of this material weakness. To rectify the material weakness, the new method of calculating the unbilled revenue estimate described above was used for periods presented in this Form 10-Q/A. See Part 1, Item 4, Controls and Procedures, for additional information regarding controls and procedures related to this material weakness.

TVA has also included in the appropriate periods in its restated consolidated financial statements other miscellaneous adjustments that were deemed to be not material by management, either individually or in the aggregate, and therefore were corrected in the period in which they were originally identified These adjustments are described in more detail in Note 2.

The effects of these restatements and miscellaneous adjustments on TVA's consolidated financial statements as of and for the quarters ended December 31, 2007, and 2006, are described in Note 2. The restatements had no impact on TVA’s cash or cash equivalents.

For the convenience of the reader, TVA is refiling its entire Quarterly Report on Form 10-Q/A for the three months ended December 31, 2007, by means of this Form 10-Q/A. However, except for the information affected by the restatement, TVA has not materially updated the information contained herein for events or transactions occurring subsequent to the date the Original 10-Q was filed with the SEC. TVA recommends that this Form 10-Q/A be read in conjunction with the reports and any amendments thereto TVA has filed with the SEC subsequent to the filing date of the Original 10-Q.

The following items have been amended principally as a result of, and to reflect, the restatement, and no other information in the Original 10-Q is amended hereby as a result of the restatement:

Part I – Item 1 – Financial Statements

Part I – Item 2 – Management's Discussion and Analysis of Financial Condition and Results of Operations

Part I – Item 4 – Controls and Procedures

Part II – Item 1 – Legal Proceedings

TVA is also filing updated certifications by the Chief Executive Officer and Chief Financial Officer as exhibits to this Form 10-Q/A.

This Form 10-Q/A is not superseding or restating financial statements contained in TVA’s quarterly reports on Form 10-Q for the quarter ended March 31, 2008, or any current report on Form 8-K filed subsequent to September 30, 2007. However, the financial statements for the three months and six months ended March 31, 2008, and March 31, 2007, which are contained in the quarterly report on Form 10-Q for the three months and six months then ended, have also been restated in an amended quarterly report on Form 10-Q/A being filed as soon as practicable after this Form 10-Q/A. Accordingly, the information in the quarterly report on Form 10-Q for the three months and six months ended March 31, 2008, should be considered in light of the information in this Form 10-Q/A.

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Forward-Looking Information	5
General Information	6

Part I - FINANCIAL INFORMATION
Item 1. Financial Statements	7
Statements of Income (Unaudited)	7
Balance Sheets (Unaudited)	8
Statements of Cash Flows (Unaudited)	9
Statements of Changes in Proprietary Capital (Unaudited)	10
Notes to Financial Statements (Unaudited)	11
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	33
Business Overview	33
Liquidity and Capital Resources	36
Results of Operations	39
Off-Balance Sheet Arrangements	43
Critical Accounting Policies and Estimates	43
Changes in Ratemaking	44
New Accounting Standards and Interpretations	44
Legislative and Regulatory Matters	45
Environmental Matters	46
Legal	46
Management Changes	50
Item 3. Quantitative and Qualitative Disclosures about Market Risk	51
Item 4. Controls and Procedures	51
Disclosure Controls and Procedures	51
Changes in Internal Control over Financial Reporting	51

Part II - OTHER INFORMATION

Item 1. Legal Proceedings	52
Item 1A. Risk Factors	52
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	52
Item 3. Defaults upon Senior Securities	52
Item 4. Submission of Matters to a Vote of Security Holders	52
Item 5. Other Information	52
Item 6. Exhibits	53

Signatures	54
Exhibit Index	55

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FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q/A (“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,” or other similar expressions.

Examples of forward-looking statements include, but are not limited to:

•

Statements regarding strategic objectives;

•

Projections regarding potential rate actions;

•

Estimates of costs of certain asset retirement obligations;

•

Estimates regarding power and energy forecasts;

•

Expectations about the adequacy of TVA’s funding of its pension plans, nuclear decommissioning trust, and asset retirement trust;

•

Estimates regarding the reduction of bonds, notes, and other evidences of indebtedness, lease/leaseback commitments, and power prepayment obligations;

•

Estimates of amounts to be reclassified from other comprehensive income to earnings over the next year;

•

TVA’s plans to continue using short-term debt to meet current obligations; and

•

The anticipated cost and timetable for placing Watts Bar Unit 2 in service.

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 laws, regulations, and administrative orders, especially those related to:

–

TVA’s protected service area,

–

The sole authority of the TVA Board to set power rates,

–

Various environmental and nuclear matters including laws, regulations, and administrative orders restricting carbon emissions and preferring certain fuels over others,

–

TVA’s management of the Tennessee River system,

–

TVA’s credit rating, and

–

TVA’s debt ceiling;

•

Loss of customers;

•

Performance of TVA’s generation and transmission assets;

•

Availability of fuel supplies;

•

Purchased power price volatility;

•

Events at facilities not owned by TVA that affect the supply of water to TVA’s generation facilities;

•

Compliance with existing environmental laws and regulations;

•

Significant delays or cost overruns in construction of generation and transmission assets;

•

Significant changes in demand for electricity;

•

Legal and administrative proceedings;

•

Weather conditions, including drought;

•

Failure of transmission facilities;

•

Events at any nuclear facility, even one that is not owned by or licensed to TVA;

•

Catastrophic events such as fires, earthquakes, floods, tornadoes, pandemics, wars, terrorist activities, and other similar events, especially if these events occur in or near TVA’s service area;

•

Reliability of purchased power providers, fuel suppliers, and other counterparties;

•

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

•

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

•

Changes in interest rates;

•

Creditworthiness of TVA, its counterparties, or its customers;

•

Rising pension costs and health care expenses;

•

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

•

Limitations on TVA’s ability to borrow money;

•

Changes in the economy;

•

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

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•

Changes in accounting standards;

•

The loss of TVA’s ability to use regulatory accounting;

•

Problems attracting and retaining skilled workers;

•

Changes in technology;

•

Changes in the market for TVA securities; and

•

Unforeseeable events.

Additionally, other risks that may cause actual results to differ from the predicted results are set forth in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations in this Quarterly Report, in Item 1A, Risk Factors and Item 7, Management’s Discussion and Analysis of Financial Conditions and Results of Operations in TVA’s Annual Report on Form 10-K, as amended, for the fiscal year ended September 30, 2007 (the “Annual Report”), and in other filings TVA makes from time-to-time with the Securities and Exchange Commission (“SEC”). 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

Unless otherwise indicated, years (2008, 2007, etc.) in this Quarterly Report refer to TVA’s fiscal years ended September 30.

Notes

References to “Notes” are to the Notes to 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 made 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 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. In addition, the public may read and copy any reports or other information that TVA files with the SEC at the SEC’s Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. TVA's SEC reports are also available to the public without charge from the web site maintained by the SEC at www.sec.gov.

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PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

TENNESSEE VALLEY AUTHORITY

STATEMENTS OF INCOME (UNAUDITED)

For the three months ended December 31

(in millions)

	2007			2006
	As Restated			As Restated
Operating revenues
Sales of electricity
Municipalities and cooperatives	$	1,913		$	1,763
Industries directly served		392			302
Federal agencies and other		25			25
Other revenue		30			36
Total operating revenues		2,360			2,126
Operating expenses
Fuel and purchased power		922			749
Operating and maintenance		580			550
Depreciation, amortization, and accretion		390			361
Tax equivalents		120			108
Loss on asset impairment (Note 7)		–			17
Total operating expenses		2,012			1,785
Operating income		348			341
Other income		3			18
Unrealized gain on derivative contracts, net (Note 1)		–			15
Interest expense
Interest on debt and leaseback obligations		341			348
Amortization of debt discount, issue, and reacquisition costs, net		5			5
Allowance for funds used during construction and nuclear fuel expenditures (Note 1)		(3	)		(49	)
Net interest expense		343			304

Net income	$	8		$	70

The accompanying Notes are an integral part of these financial statements.

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TENNESSEE VALLEY AUTHORITY

BALANCE SHEETS

(in millions)

ASSETS
	December 31			September 30
	2007			2007
	As Restated
Current assets	(Unaudited)
Cash and cash equivalents	$	158		$	165
Restricted cash and investments (Note 1)		127			150
Accounts receivable, net (Note 1)		1,181			1,458
Inventories and other		768			663
Total current assets		2,234			2,436

Property, plant, and equipment
Completed plant		38,918			38,811
Less accumulated depreciation		(16,204	)		(15,937	)
Net completed plant		22,714			22,874
Construction in progress		1,487			1,286
Nuclear fuel and capital leases		708			672
Total property, plant, and equipment, net		24,909			24,832

Investment funds		1,132			1,169

Regulatory and other long-term assets (Note 1)
Deferred nuclear generating units		3,032			3,130
Other regulatory assets		1,924			1,790
Subtotal		4,956			4,920
Other long-term assets		404			375
Total regulatory and other long-term assets		5,360			5,295

Total assets	$	33,635		$	33,732

LIABILITIES AND PROPRIETARY CAPITAL

Current liabilities
Accounts payable and accrued liabilities	$	940		$	1,205
Collateral funds held		144			157
Accrued interest		305			406
Current portion of leaseback obligations		43			43
Current portion of energy prepayment obligations		106			106
Short-term debt, net		1,565			1,422
Current maturities of long-term debt (Note 4)		2,090			90
Total current liabilities		5,193			3,429

Other liabilities
Other liabilities		2,141			2,067
Regulatory liabilities (Note 1)		145			83
Asset retirement obligations		2,219			2,189
Leaseback obligations		1,028			1,029
Energy prepayment obligations (Note 1)		1,006			1,032
Total other liabilities		6,539			6,400

Long-term debt, net (Note 4)		19,105			21,099

Total liabilities		30,837			30,928

Commitments and contingencies

Proprietary capital
Appropriation investment		4,738			4,743
Retained earnings		1,768			1,763
Accumulated other comprehensive (loss)		(23	)		(19	)
Accumulated net expense of nonpower programs		(3,685	)		(3,683	)
Total proprietary capital		2,798			2,804

Total liabilities and proprietary capital	$	33,635		$	33,732

The accompanying Notes are an integral part of these financial statements.

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TENNESSEE VALLEY AUTHORITY

STATEMENTS OF CASH FLOWS (UNAUDITED)

For the three months ended December 31

(in millions)

	2007			2006
	As Restated			As Restated
Cash flows from operating activities
Net income	$	8		$	70
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, amortization, and accretion		395			365
Nuclear refueling outage amortization		25			21
Loss on asset impairment		–			18
Amortization of nuclear fuel		44			27
Non-cash retirement benefit expense		35			50
Net unrealized gain on derivative contracts		–			(15	)
Prepayment credits applied to revenue		(26	)		(26	)
Fuel cost adjustment deferral		34			6
Other, net		(2	)		(18	)
Changes in current assets and liabilities
Accounts receivable, net		247			192
Inventories and other		(103	)		(78	)
Accounts payable and accrued liabilities		(200	)		(56	)
Accrued interest		(100	)		(107	)
Pension contributions		(19	)		(19	)
Refueling outage costs		(36	)		(41	)
Net cash provided by operating activities		302			389

Cash flows from investing activities
Construction expenditures		(365	)		(398	)
Combustion turbine asset acquisitions		–			(98	)
Nuclear fuel expenditures		(137	)		(33	)
Change in restricted cash and investments		23			(8	)
Purchases of investments, net		(2	)		(1	)
Loans and other receivables
Advances		(4	)		(1	)
Repayments		3			4
Proceeds from sale of receivables/loans		–			2
Other, net		–			(1	)
Net cash used in investing activities		(482	)		(534	)

Cash flows from financing activities
Long-term debt
Issues		41			9
Redemptions and repurchases		–			(77	)
Short-term issues, net		143			190
Payments on leaseback financing		(1	)		(1	)
Payments to U.S. Treasury		(10	)		(10	)
Net cash provided by financing activities		173			111

Net change in cash and cash equivalents		(7	)		(34	)
Cash and cash equivalents at beginning of period		165			536

Cash and cash equivalents at end of period	$	158		$	502

The accompanying Notes are an integral part of these financial statements.

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TENNESSEE VALLEY AUTHORITY

STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL

For the three months ended December 31

(in millions)

	Appropriation Investment			Retained Earnings (Restated)			Accumulated Other Comprehensive Income (Loss)			Accumulated Net Expense of Stewardship Programs			Total (Restated)			Comprehensive Income (Loss)

Balance at September 30, 2006 (as restated)	$	4,763		$	1,349		$	43		$	(3,672	)	$	2,483
Net income (loss) (as restated)		–			72			–			(2	)		70		$	70
Return on Power Facility Appropriation Investment		–			(5	)		–			–			(5	)		–
Accumulated other comprehensive loss (Note 3)		–			–			(15	)		–			(15	)		(15	)
Return of Power Facility Appropriation Investment		(5	)		–			–			–			(5	)		–

Balance at December 31, 2006 (unaudited) (as restated)	$	4,758		$	1,416		$	28		$	(3,674	)	$	2,528		$	55

Balance at September 30, 2007 (as restated)	$	4,743		$	1,763		$	(19	)	$	(3,683	)	$	2,804
Net income (loss) (as restated)		–			10			–			(2	)		8		$	8
Return on Power Facility Appropriation Investment		–			(5	)		–			–			(5	)		–
Accumulated other comprehensive loss (Note 3)		–			–			(4	)		–			(4	)		(4	)
Return of Power Facility Appropriation Investment		(5	)		–			–			–			(5	)		–

Balance at December 31, 2007 (unaudited) (as restated)	$	4,738		$	1,768		$	(23	)	$	(3,685	)	$	2,798		$	4

The accompanying Notes are an integral part of these financial statements.

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NOTES TO FINANCIAL STATEMENTS (unaudited)

(Dollars in millions except where noted)

1. Summary of Significant Accounting Policies

General

The Tennessee Valley Authority (“TVA”) is a wholly-owned corporate agency and instrumentality of the United States. TVA was created by the U.S. Congress in 1933 by virtue of the Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee (as amended, the “TVA Act”). TVA was created to improve navigation on the Tennessee River, reduce flood damage, provide agricultural and industrial development, and provide electric power to the Tennessee Valley region. TVA manages the Tennessee River and its tributaries for multiple river-system purposes, such as navigation; flood damage reduction; power generation; environmental stewardship; shoreline use; and water supply for power plant operations, consumer use, recreation, and industry.

Substantially all TVA revenues and assets are attributable to the power program. TVA provides power in most of Tennessee, northern Alabama, northeastern Mississippi, and southwestern Kentucky, and in portions of northern Georgia, western North Carolina, and southwestern Virginia to a population of approximately 8.8 million people. The power program has historically been separate and distinct from the stewardship programs. The power program is required to be self-supporting from power revenues and proceeds from power financings, such as proceeds from the issuance of bonds, notes, and 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 power facilities (the “Power Facility Appropriation Investment”). Until 2000, most of the funding for TVA’s stewardship programs was provided by congressional appropriations. These programs are now funded with power revenues, except for certain stewardship activities that generate various revenues and user fees. These activities related to stewardship properties do not meet the criteria of an operating segment pursuant to Statement of Financial Accounting Standard (“SFAS”) No. 131, “Disclosures About Segments of an Enterprise and Related Information.” Accordingly, stewardship assets and properties are included as part of the power program, TVA’s only operating segment.

Power rates are established by the TVA board of directors (“TVA Board”) as authorized by the TVA Act. The TVA Act requires TVA to charge rates for power that will produce gross revenues sufficient to provide funds for operation, maintenance, and administration of its power system; payments to states and counties in lieu of taxes; debt service on outstanding indebtedness; payments to the U.S. Treasury in repayment of and as a return on the Power Facility 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 Facility 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 the prior approval of or subsequent review by any state or federal regulatory body.

Basis of Presentation

TVA prepares its interim financial statements in conformity with generally accepted accounting principles (“GAAP”) accepted in the United States for interim financial information. Accordingly, TVA’s interim financial statements do not include all of the information and notes required by GAAP for complete financial statements. Because the accompanying interim financial statements do not include all of the information and footnotes required by GAAP for complete financial statements, they should be read in conjunction with the audited financial statements for the year ended September 30, 2007, and the notes thereto, which are contained in TVA’s Annual Report on Form 10-K, as amended, for the fiscal year ended September 30, 2007 (the “Annual Report”).

The amounts included in the accompanying interim financial statements are unaudited but, in the opinion of TVA management, reflect all adjustments, which consist solely of normal recurring adjustments, necessary to fairly present TVA’s financial position and results of operations for the interim periods. Due to seasonal weather variations and the timing of planned maintenance and refueling outages of electric generating units, the results of operations for interim periods are not necessarily indicative of amounts expected for the entire year.

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Use of Estimates

In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the amounts of revenues and expenses reflected during the reporting period. Actual results could differ from those estimates.

Fiscal Year

TVA’s fiscal year ends September 30. Unless otherwise indicated, years (2008, 2007, etc.) refer to TVA’s fiscal years.

Restricted Cash and Investments

As of December 31, 2007, and September 30, 2007, TVA had $127 million and $150 million, respectively, in Restricted cash and investments on its Balance Sheets primarily related to collateral posted with TVA by a swap counterparty in accordance with certain credit terms included in the swap agreement. This resulted in the funds being reported in Restricted cash and investments.

Accounts Receivable

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

Accounts Receivable

	At December 31 2007			At September 30 2007
	As Restated
Power receivables billed	$	254		$	316
Power receivables unbilled		804			986
Fuel cost adjustment unbilled		102			132
Total power receivables		1,160			1,434
Other receivables		23			26
Allowance for uncollectible accounts		(2	)		(2	)
Net accounts receivable	$	1,181		$	1,458

Cost-Based Regulation

Regulatory assets capitalized under the provisions of SFAS No. 71, “Accounting for the Effects of Certain Types of Regulation,” are included in Accounts receivable, Deferred nuclear generating units, and Other regulatory assets on the December 31, 2007, and the September 30, 2007, Balance Sheets. Components of Other regulatory assets include certain charges related to the closure and removal from service of nuclear generating units, debt reacquisition costs, deferred outage costs, deferred capital lease asset costs, deferred losses relating to TVA’s financial trading program, FCA, unrealized losses on certain swaps and swaptions contracts, and unfunded benefit costs. All regulatory assets are probable of recovery in future revenues. Components of Regulatory liabilities include unrealized gains on coal purchase contracts, a reserve for future generation, and capital lease liabilities.

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TVA’s regulatory assets and liabilities are summarized in the table below.

TVA Regulatory Assets and Liabilities

	At December 31 2007		At September 30 2007
	As Restated
Regulatory Assets:
Unfunded benefit costs	$	951	$	973
Nuclear decommissioning costs		482		419
Debt reacquisition costs		205		210
Deferred losses relating to TVA’s financial trading program		2		8
Deferred outage costs		107		96
Deferred capital lease asset costs		63		66
Unrealized losses on certain swap and swaption contracts		99		–
Fuel cost adjustment: long-term		15		18
Subtotal		1,924		1,790
Deferred nuclear generating units		3,032		3,130
Subtotal		4,956		4,920
Fuel cost adjustment receivable: short-term		102		132

Total	$	5,058	$	5,052


Regulatory Liabilities:
Unrealized gains on coal purchase contracts	$	83	$	16
Capital lease liabilities		62		67
Subtotal		145		83
Reserve for future generation		73		74

Total	$	218	$	157

In the first quarter of 2008, TVA began using regulatory accounting treatment to defer the unrealized mark to market gains and losses on certain swap and swaption contracts to better match the income statement recognition of gain and loss with the economic reality of when these transactions actually settle. The value of the swap and swaptions will still be recorded on TVA’s balance sheet, and any interest expense impacts will continue to be reflected in TVA’s income statement. The deferred loss on the value of the swaps and swaptions was $99 million for the first quarter of 2008 and is included as a Regulatory asset on the December 31, 2007, Balance Sheet. See Swaps and Swaptions in this Note 1.

TVA established a reserve for future generation funded by power customers which is also classified as a regulatory liability. Because of the nature of the reserve, it is considered as an offset to Property, plant, and equipment on the December 31, 2007, and September 30, 2007, Balance Sheets. See Reserve for Future Generation in this Note 1.

Reserve for Future Generation

During the first quarter of 2007, TVA began collecting in rates amounts intended to fund future generation based on the need for additional generating capacity to meet future power demand in TVA’s service area. Because these amounts were intended to fund future costs, they were originally deferred as a regulatory liability. The funds were based on a predetermined rate applied to electricity sales approved as part of TVA’s 2007 budget. Collections for the three months ended December 31, 2006, amounted to $13 million, and total collections for the year ended September 30, 2007, amounted to $76 million. These amounts were recorded as a regulatory liability on the December 31, 2006, and September 30, 2007, Balance Sheets, respectively, as a component of Completed plant. Following the purchase of two combustion turbine facilities, these funds are being applied as credits to Completed plant and are reflected on the September 30, 2007, Balance Sheet. These funds collected for future generation are being amortized to revenue in order to match revenue with the corresponding depreciation expense of the facilities on the Statement of Income. This revenue recognition process began when the facilities were placed into service. The reserve for future generation was not extended beyond 2007. The balance of the reserve for future generation was $73 million at December 31, 2007, and $74 million at September 30, 2007. TVA recognized revenue of $1 million during the first quarter of 2008 consistent with the manner in which the related assets are being depreciated.

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Energy Prepayment Obligations

Prior to 2005, TVA entered into sales agreements with 36 customers for 54.5 discounted energy units totaling $54.5 million. Total credits applied to power billings on a cumulative basis from these arrangements through December 31, 2007, exceeded $27.2 million. Of this amount, over $1 million was recognized as revenue for each of the quarterly periods ended December 31, 2007 and 2006.

In November 2003, TVA, Memphis Light, Gas, and Water Division (“MLGW”), and the City of Memphis entered into agreements whereby MLGW prepaid a portion of its power requirements for 15 years for a fixed amount of kilowatt-hours. The amount of the prepayment was $1.5 billion. The prepayment credits are being applied to reduce MLGW’s monthly power bill on a straight-line basis over the same 15-year period. Total credits applied to power billings on a cumulative basis through December 31, 2007, exceeded $415 million. Of this amount, $25 million was recognized as revenue for each of the quarterly periods ended December 31, 2007 and 2006. These amounts were based on the ratio of kilowatt-hours of electricity delivered to the total kilowatt-hours under contract.

At December 31, 2007 and September 30, 2007, obligations for these energy prepayments were $1,112 million and $1,138 million, respectively. These amounts are included in Energy prepayment obligations and Current portion of energy prepayment obligations on the December 31, 2007, and September 30, 2007, Balance Sheets.

Asset Retirement Obligations

In accordance with the provisions of SFAS No. 143, “Accounting for Asset Retirement Obligations,” TVA recognizes the fair value of legal obligations associated with the retirement of certain tangible long-lived assets. The fair value of the liability is added to the book value of the associated asset. The liability increases due to the passage of time (accretion expense), based on the time value of money, until the obligations settle. Subsequent to the initial recognition, the future liability is adjusted for any periodic revisions to the expected cost of the retirement obligation (changes in estimates to future cash flows) and for accretion of the liability due to the passage of time.

During the first quarter of 2008, TVA’s total asset retirement obligation (“ARO”) increased $30 million due to accretion expense. The nuclear accretion expense of $23 million was deferred and charged to a regulatory asset in accordance with SFAS No. 71. The remaining accretion expense of $7 million, related to coal-fired and gas/oil combustion turbine plants, asbestos, and polychlorinated biphenyls (“PCBs”), was expensed during the first quarter of 2008. During the first quarter of 2007, TVA’s total ARO liability increased $22 million due to accretion expense. The nuclear accretion expense of $15 million was deferred and charged to a regulatory asset in accordance with SFAS No. 71. The remaining accretion expense of $7 million, related to coal-fired and gas/oil combustion turbine plants, asbestos, and PCBs, was expensed during the first quarter of 2007.

Reconciliation of Asset Retirement Obligation Liability Three Months Ended December 31

	2007		2006
Balance at beginning of period	$	2,189	$	1,985

Add: ARO (accretion) expense
Nuclear accretion (recorded as a regulatory asset)		23		15
Non-nuclear accretion (charged to expense)		7		7
		30		22

Balance at end of period	$	2,219	$	2,007

Allowance for Funds Used During Construction

TVA capitalizes interest, as an allowance for funds used during construction ("AFUDC"), based on the average interest rate of TVA’s outstanding debt. The allowance is applicable to construction in progress related to certain projects and certain nuclear fuel inventories. TVA will continue to capitalize a portion of current interest costs associated with funds invested in most nuclear fuel inventories, but interest on funds invested in construction projects will be capitalized beginning in 2008 only if (1) the expected total cost of a project is $1 billion or more and (2) the estimated construction period is at least three years.

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Swaps and Swaptions

From time to time TVA has entered into call monetization transactions using swaptions to hedge the value of call provisions on certain of its Bond issues. A swaption essentially grants a third party an option to enter into a swap agreement with TVA under which TVA receives a floating rate of interest and pays the third party a fixed rate of interest equal to the interest rate on the Bond issue whose call provision TVA monetized. Selling such an option creates a liability for TVA until such time as TVA buys back the option or until the option matures.

These call monetization transactions result in long-term liabilities which are marked to market each quarter. In accordance with the accounting policy that was in effect on September 30, 2007, the changes in the value of these liabilities were reported as unrealized gains or losses through TVA’s income statement in accordance with SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities.” The volatility of the valuations resulted in the recognition of sizable amounts of non-cash expense or income, which affected net income.

The TVA Board approved, beginning in 2008, the utilization of regulatory accounting treatment for swaps and swaptions related to call monetization transactions in order to better match the income statement recognition of gain and loss with the economic reality of when these transactions actually settle. This treatment removes the non-cash impacts to TVA’s earnings that result from marking the value of these instruments to market each quarter. The value of the swaps and swaptions will still be recorded on TVA’s balance sheet, and any interest expense impacts will continue to be reflected in TVA’s income statement. The deferred loss on the value of the swaps and swaptions for the first quarter of 2008 was $99 million and is included as a Regulatory asset on the December 31, 2007, Balance Sheet.

Impact of New Accounting Standards and Interpretations

Accounting for Defined Benefit Pension and Other Postretirement Plans. On September 30, 2007, TVA adopted the provisions contained within SFAS No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans — an amendment of FASB Statements No. 87, 88, 106, and 132(R).” This standard requires employers to fully recognize within their financial statements the obligations associated with single-employer defined benefit pension, retiree healthcare, and other postretirement plans. Specifically, the new standard requires an employer to recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year (with limited exceptions); and recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur. Such changes are to be reported within comprehensive income of a business entity (except that regulated entities may report such changes as regulatory assets and/or liabilities in accordance with the provisions of SFAS No. 71), and within changes in net assets of a not-for-profit organization.

TVA’s 2007 adoption of SFAS No. 158 resulted in the recognition of the following amounts on its Balance Sheet at September 30, 2007: additional regulatory assets of $475 million (including the reclassification of $246 million in unamortized prior service cost previously classified as intangible assets) resulting in post-SFAS No. 158 benefit regulatory assets of $973 million; and additional pension and postretirement obligations of $330 million and $143 million, and $2 million classified as accumulated other comprehensive gain, resulting in post-SFAS No. 158 benefit obligations of $1,128 million. The net amount of recognizing such amounts increased total assets and liabilities by $475 million at September 30, 2007.

Fair Value Measurements. In September 2006, Financial Accounting Standards Board (“FASB”) issued SFAS No. 157, “Fair Value Measurements.” This standard provides guidance for using fair value to measure assets and liabilities that currently require fair value measurement. The standard also responds to investors’ requests for expanded information about the extent to which companies measure assets and liabilities at fair value, the information used to measure fair value, and the effect of fair value measurements on earnings. SFAS No. 157 applies whenever other standards require (or permit) assets or liabilities to be measured at fair value but does not expand the use of fair value in any new circumstances. SFAS No. 157 establishes a fair value hierarchy that prioritizes the information used to develop measurement assumptions. The provisions of SFAS No. 157 are effective for financial statements issued for fiscal years beginning after November 15, 2008, and interim periods within those fiscal years. At this time, TVA is evaluating the requirements of this standard and has not yet determined the impact of its implementation, which may or may not be material to TVA’s results of operations or financial position.

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Fair Value Option. In February 2007, FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities — Including an amendment of FASB Statement No. 115.” This standard permits an entity to choose to measure many financial instruments and certain other items at fair value. The fair value option established by SFAS No.159 permits all entities to choose to measure eligible items at fair value at specified election dates. A business entity will report unrealized gains and losses on items for which the fair value option has been elected in earnings at each subsequent reporting date. Most of the provisions in this statement are elective. The provisions of SFAS No. 159 are effective as of the beginning of an entity’s first fiscal year that begins after November 15, 2007. Early adoption is permitted as of the beginning of the previous fiscal year provided that the entity makes that choice in the first 120 days of that fiscal year and also elects to apply the provisions of SFAS No. 157. At this time, TVA is evaluating the requirements of this standard and has not yet determined the potential impact of its implementation, which may or may not be material to TVA’s results of operations or financial position.

Offsetting Amounts. On April 30, 2007, FASB issued FASB Staff Position (“FSP”) FIN No. 39-1, “Amendment of FASB Interpretation No. 39,” which addresses certain modifications to FASB Interpretation No. 39, “Offsetting of Amounts Related to Certain Contracts.” This FSP replaces the terms “conditional contracts” and “exchange contracts” with the term “derivative instruments” as defined in SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities.” The FSP also permits a reporting entity to offset fair value amounts recognized for the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. The guidance in the FSP is effective for fiscal years beginning after November 15, 2007, with early application permitted. At this time, TVA is evaluating the requirements of this guidance and has not yet determined the potential impact of its implementation, which may or may not be material to TVA’s financial position.

2. Restatement

The accompanying financial statements as of December 31, 2007, and 2006, and September 30, 2007, have been restated. TVA determined that the method implemented to estimate unbilled revenues in September 2006 had resulted in errors in unbilled revenue presented in TVA’s financial statements for the fiscal years ended September 30, 2006, and 2007, and the quarterly periods ended December 31, 2006, March 31, 2007, June 30, 2007, December 31, 2007, and March 31, 2008. There was no effect on periods prior to the three months ended September 30, 2006.

Under TVA’s end-use billing arrangements with its distributors, TVA relies on the distributors to report their end-use sales. Because of the delay between the wholesale delivery of power to the customer and the report of end-use sales to TVA, TVA must estimate the unbilled revenue at the end of each financial reporting period. In September 2006, TVA implemented a change in methodology for estimating unbilled revenue for electricity sales which resulted in an increase of $232 million in unbilled revenue (or 2.6 percent of operating revenues) for 2006.

TVA has used a new process for estimating unbilled revenue for the three months ended December 31, 2007, and 2006. This process carries over only the portion of sales from the distributor’s meter read date to the month-end. Those sales, along with the current month sales, are then priced at rates based on each distributor’s customer and product mix. Additionally, a true-up component has been added to the unbilled calculation to reflect any timing differences that occur between the retail and wholesale billing cycles. Due to the new process, an adjustment was made to increase revenue for the three months ended December 31, 2007 and 2006, by $8 million and $21 million, respectively.

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The unbilled revenue error also affected the application of distributor prepayments. The balance in the distributors’ unbilled accounts receivable is offset by a reduction in the advance collections of those customers who make prepayments for their power. As a result of the change in unbilled revenue, the balances in the unbilled receivable and advance collections accounts were adjusted upward by less than $1 million as of December 31, 2007.

TVA has evaluated these errors and determined that the impact was an overstatement of net income for the fiscal year ended September 30, 2006, and an understatement of net income for the fiscal year ended September 30, 2007, and the three months ended December 31, 2007. The changes to the financial statements as of or for the respective periods primarily involves accounts receivable and retained earnings on the balance sheets, and operating revenues and net income on the statements of income. The errors and restatements have no impact on cash and cash equivalents.

In addition to the unbilled revenue and FCA adjustments, there were certain miscellaneous items that were previously deemed to be immaterial by management which have been corrected in the period in which they were originally identified. Summary restatements tables are presented below. References in the “Note” column correspond to lines on the Statements of Income and Balance Sheets following these tables. Accordingly, previously reported amounts are being restated to properly reflect the accounting for these items as follows:

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Statements of Income

Summary of Restatements

For the Three Months Ended December 31

	Description of Adjustment	2007			Note	2006			Note
Operating revenues	Unbilled revenue adjustments	$	8			$	21
	Reclassification of expenses previously netted with revenue		2				1
			10		I08-1		22		I07-1

Operating expenses	Fuel cost adjustment		(14	)			6
	Change in period for depreciation expense		–				5
	Change in loss on asset impairment		–				(5	)
	Additional legal expense		(3	)			–
	Financing cost interest reclassification		(12	)			(12	)
	Reclassification of expenses previously netted with revenue		3				3
			(26	)	I08-2		(3	)	I07-2

Operating income			36				25

Other income	Additional legal expense		–				4
	Reclassification of other income previously reported as revenue		1				2
			1		I08-3		6		I07-3

Interest expense	Financing cost interest reclassification		12		I08-4		12		I07-4

Net income		$	25			$	19

Balance Sheet

Summary of Restatements

December 31, 2007

	Description of Adjustment	Amount			Note
Current assets
Accounts receivable	Unbilled revenue adjustments	$	(118	)
Accounts receivable	Fuel cost adjustments		(46	)
			(164	)	B08-1
Regulatory and other long-term assets
Regulatory assets	Fuel cost adjustments		12		B08-2
Total restatement of assets		$	(152	)

Current liabilities
Accrued liabilities	Unbilled revenue adjustments	$	(1	)	B08-3
Proprietary capital
Retained earnings	Unbilled revenue adjustments		8
Retained earnings	Fuel cost adjustments		14
Retained earnings	Legal reserve adjustment		3
Retained earnings	Beginning retained earnings adjustment		(176	)
			(151	)	B08-4
Total restatement of liabilities and proprietary capital		$	(152	)

Accordingly, previously reported amounts are being restated to properly reflect the accounting for these items as follows:

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Statements of Income

The following table summarizes the statements of income for the periods indicated, giving effect to the restatement adjustments described above and showing previously reported amounts and restated amounts for the three months ended December 31, 2007, and 2006.

Statements of Income

Three Months Ended December 31

	2007										2006
	As Previously Reported			Increase (Decrease)			Note	As Restated			As Previously Reported			Increase (Decrease)			Note	As Restated
Operating revenues
Sales of electricity
Municipalities and cooperatives	$	1,905		$	8			$	1,913		$	1,742		$	21			$	1,763
Industries directly served		392			–				392			302			–				302
Federal agencies and other		25			–				25			25			–				25
Other revenue		28			2				30			35			1				36
Total operating revenues		2,350			10		I08-1		2,360			2,104			22		I07-1		2,126

Operating expenses
Fuel and purchased power		935			(13	)			922			739			10				749
Operating and maintenance		592			(12	)			580			563			(13	)			550
Depreciation, amortization, and accretion		390			–				390			356			5				361
Tax equivalents		121			(1	)			120			108			–				108
Loss on asset impairment		–			–				–			22			(5	)			17
Total operating expenses		2,038			(26	)	I08-2		2,012			1,788			(3	)	I07-2		1,785

Operating income		312			36				348			316			25				341

Other income, net		2			1		I08-3		3			12			6		I07-3		18

Unrealized gain on derivative contracts, net		–			–				–			15			–				15

Interest expense
Interest on debt and leaseback obligations		329			12				341			336			12				348
Amortization of debt discount, issue, and reacquisition costs, net		5			–				5			5			–				5
Allowance for funds used during construction and nuclear fuel expenditures		(3	)		–				(3	)		(49	)		–				(49	)
Net interest expense		331			12		I08-4		343			292			12		I07-4		304

Net (loss) income	$	(17	)	$	25			$	8		$	51		$	19			$	70

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Balance Sheet

The following table sets forth the balance sheet giving effect to the restatement and other adjustments described above and showing previously reported amounts and restated amounts as of December 31, 2007.

Balance Sheet

	December 31, 2007
	As Previously Reported			Increase (Decrease)			Note	As Restated

ASSETS
Current assets
Cash and cash equivalents	$	158		$	–			$	158
Restricted cash and investments		127			–				127
Accounts receivable, net		1,345			(164	)			1,181
Inventories and other		768			–				768
Total current assets		2,398			(164	)	B08-1		2,234

Property, plant, and equipment
Completed plant		38,918			–				38,918
Less accumulated depreciation		(16,204	)		–				(16,204	)
Net completed plant		22,714			–				22,714
Construction in progress		1,487			–				1,487
Nuclear fuel and capital leases		708			–				708
Total property, plant, and equipment, net		24,909			–				24,909

Investment funds		1,132			–				1,132

Regulatory and other long-term assets
Deferred nuclear generating units		3,032			–				3,032
Other regulatory assets		1,912			12				1,924
Subtotal		4,944			12				4,956
Other long-term assets		404			–				404
Total regulatory and other long-term assets		5,348			12		B08-2		5,360

Total assets	$	33,787		$	(152	)		$	33,635

LIABILITIES AND PROPRIETARY CAPITAL

Current liabilities
Accounts payable and accrued liabilities	$	941		$	(1	)		$	940
Collateral funds held		144			–				144
Accrued interest		305			–				305
Current portion of leaseback obligations		43			–				43
Current portion of energy prepayment obligations		106			–				106
Short-term debt, net		1,565			–				1,565
Current maturities of long-term debt		2,090			–				2,090
Total current liabilities		5,194			(1	)	B08-3		5,193

Other liabilities
Other liabilities		2,141			–				2,141
Regulatory liabilities		145			–				145
Asset retirement obligations		2,219			–				2,219
Leaseback obligations		1,028			–				1,028
Energy prepayment obligations		1,006			–				1,006
Total other liabilities		6,539			–				6,539

Long-term debt, net		19,105			–				19,105

Total liabilities		30,838			(1	)			30,837

Commitments and contingencies

Proprietary capital
Appropriation investment		4,738			–				4,738
Retained earnings		1,919			(151	)			1,768
Accumulated other comprehensive (loss) income		(23	)		–				(23	)
Accumulated net expense of stewardship programs		(3,685	)		–				(3,685	)
Total proprietary capital		2,949			(151	)	B08-4		2,798

Total liabilities and proprietary capital	$	33,787		$	(152	)		$	33,635

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Statements of Cash Flows

The following table summarizes the statements of cash flows for the periods indicated, giving effect to the restatement adjustments described above and showing previously reported amounts and restated amounts for the three months ended December 31, 2007, and 2006.

Statements of Cash Flows For the Three Months Ended December 31

	2007									2006
	As Previously Reported			Increase (Decrease)			As Restated			As Previously Reported			Increase (Decrease)			As Restated
Cash flows from operating activities
Net (loss) income	$	(17	)	$	25		$	8		$	51		$	19		$	70
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, amortization, and accretion		395			–			395			360			5			365
Nuclear refueling outage amortization		25			–			25			21			–			21
Loss on asset impairment		–			–			–			22			(4	)		18
Amortization of nuclear fuel		44			–			44			27			–			27
Non-cash retirement benefit expense		35			–			35			50			–			50
Net unrealized gain on derivative contracts		–			–			–			(15	)		–			(15	)
Prepayment credits applied to revenue		(26	)		–			(26	)		(26	)		–			(26	)
Fuel cost adjustment deferral		47			(13	)		34			–			6			6
Other, net		1			(3	)		(2	)		(15	)		(3	)		(18	)
Changes in current assets and liabilities
Accounts receivable, net		256			(9	)		247			214			(22	)		192
Inventories and other		(103	)		–			(103	)		(78	)		–			(78	)
Accounts payable and accrued liabilities		(284	)		84			(200	)		(120	)		64			(56	)
Accrued interest		(100	)		–			(100	)		(107	)		–			(107	)
Pension contributions		(19	)		–			(19	)		(19	)		–			(19	)
Refueling outage costs		(36	)		–			(36	)		(41	)		–			(41	)
Net cash provided by operating activities		218			84			302			324			65			389

Cash flows from investing activities
Construction expenditures		(335	)		(30	)		(365	)		(344	)		(54	)		(398	)
Combustion turbine asset acquisitions		–			–			–			(98	)		–			(98	)
Nuclear fuel expenditures		(83	)		(54)			(137	)		(22	)		(11	)		(33	)
Change in restricted cash and investments		23			–			23			(8	)		–			(8	)
Purchases of investments, net		(2	)		–			(2	)		(1	)		–			(1	)
Loans and other receivables
Advances		(4	)		–			(4	)		(1	)		–			(1	)
Repayments		3			–			3			4			–			4
Proceeds from sale of receivables/loans		–			–			–			2			–			2
Other, net		–			–			–			(1	)		–			(1	)
Net cash used in investing activities		(398	)		(84)			(482	)		(469	)		(65	)		(534	)

Cash flows from financing activities
Long-term debt
Issues		41			–			41			9			–			9
Redemptions and repurchases		–			–			–			(77	)		–			(77	)
Short-term issues, net		143			–			143			190			–			190
Payments on leaseback financing		(1	)		–			(1	)		(1	)		–			(1	)
Payments to U.S. Treasury		(10	)		–			(10	)		(10	)		–			(10	)
Net cash provided by financing activities		173			–			173			111			–			111

Net change in cash and cash equivalents		(7	)		–			(7	)		(34	)		–			(34	)
Cash and cash equivalents at beginning of period		165			–			165			536			–			536

Cash and cash equivalents at end of period	$	158		$	–		$	158		$	502		$	–		$	502

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Statements of Changes in Proprietary Capital

The following table summarizes the statements of changes in proprietary capital for the periods indicated, giving effect to the restatement adjustments described above and showing previously reported amounts and restated amounts for the three months ended December 31, 2007, and 2006.

Statements of Changes in Proprietary Capital

	Appropriation Investment			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Accumulated Net Expense of Stewardship Programs			Total			Comprehensive Income (loss)

Balance at September 30, 2006 (as previously reported)	$	4,763		$	1,565		$	43		$	(3,672	)	$	2,699
Increase (decrease)		–			(216	)		–			–			(216	)
Balance at September 30, 2006 (as restated)		4,763			1,349			43			(3,672	)		2,483
Net income (loss)		–			53			–			(2	)		51		$	51
Return on Power Facility Appropriation Investment		–			(5	)		–			–			(5	)		–
Accumulated other comprehensive (loss)		–			–			(15	)		–			(15	)		(15	)
Return of Power Facility Appropriation Investment		(5	)		–			–			–			(5	)		–

Balance at December 31, 2006 (as previously reported) (unaudited)		4,758			1,613			28			(3,674	)		2,725			36
Increase (decrease)		–			(197	)		–			–			(197	)		19
Balance at December 31, 2006 (as restated) (unaudited)	$	4,758		$	1,416		$	28		$	(3,674	)	$	2,528		$	55

Balance at September 30, 2007 (as previously reported)	$	4,743		$	1,939		$	(19	)	$	(3,683	)	$	2,980
Increase (decrease)		–			(176	)		–			–			(176	)
Balance at September 30, 2007 (as restated)		4,743			1,763			(19	)		(3,683	)		2,804
Net (loss)		–			(15	)		–			(2	)		(17	)	$	(17	)
Return on Power Facility Appropriation Investment		–			(5	)		–			–			(5	)		–
Accumulated other comprehensive (loss)		–			–			(4	)		–			(4	)		(4	)
Return of Power Facility Appropriation Investment		(5	)		–			–			–			(5	)		–

Balance at December 31, 2007 (as previously reported) (unaudited)		4,738			1,919			(23	)		(3,685	)		2,949			(21	)
Increase (decrease)		–			(151	)		–			–			(151	)		25
Balance at December 31, 2007 (as restated) (unaudited)	$	4,738		$	1,768		$	(23	)	$	(3,685	)	$	2,798		$	4

Statements of Changes in Proprietary Capital restatements are due to changes in net income and retained earnings resulting from the restatement process. Please refer to the Statement of Net Income for discussion of the changes in net income. Please refer to the Balance Sheets for discussion of changes in Retained Earnings. All other components remain consistent with the presentation noted in the original statement presentation.

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Accounts Receivable

The following table summarizes the types and amounts of receivables for the periods indicated, giving effect to the restatement adjustments described above and showing previously reported amounts and restated amounts as of December 31, 2007.

Accounts Receivable

	December 31, 2007
	As Previously Reported			Increase (Decrease)			As Restated
Power receivables billed	$	254		$	–		$	254
Power receivables unbilled		922			(118	)		804
Fuel cost adjustment unbilled		148			(46	)		102
Subtotal power receivables		1,324			(164	)		1,160
Other receivables		23			–			23
Allowance for uncollectible accounts		(2	)		–			(2	)
Net accounts receivable	$	1,345		$	(164	)	$	1,181

Regulatory Assets

The following table summarizes the types and amounts of regulatory assets for the periods indicated, giving effect to the restatement adjustments described above and showing previously reported amounts and restated amounts as of December 31, 2007.

Regulatory Assets

	December 31, 2007
	As Previously Reported		Increase (Decrease)			As Restated

Unfunded benefit costs	$	951	$	–		$	951
Nuclear decommissioning costs		482		–			482
Debt reacquisition costs		205		–			205
Deferred losses relating to TVA’s financial trading program		2		–			2
Deferred outage costs		107		–			107
Deferred capital lease asset costs		63		–			63
Unrealized losses on certain swaps and swaptions		99		–			99
Fuel cost adjustment: long term		3		12			15
Subtotal		1,912		12			1,924
Deferred nuclear generating units		3,032		–			3,032
Subtotal		4,944		12			4,956
Fuel Cost Adjustment Receivable: short term		148		(46	)		102

Total	$	5,092	$	(34	)	$	5,058

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3. Accumulated Other Comprehensive Income (Loss)

SFAS No. 130, “Reporting Comprehensive Income,” requires the disclosure of other comprehensive income to reflect changes in capital that result from transactions and economic events from non-owner sources. The decrease in Other comprehensive income for the three months ended December 31, 2007, and for the three months ended December 31, 2006, was due to unrealized losses related to mark-to-market valuation adjustments for certain derivative instruments.

Total Other Comprehensive (Loss) Income Activity

	Three Months Ended December 31
	2007			2006

Accumulated other comprehensive (loss) income at beginning of period	$	(19	)	$	43
Changes in fair value:
Foreign currency swaps		(4	)		(16	)
Inflation swap		–			1
Accumulated other comprehensive (loss) income at end of period	$	(23	)	$	28

Note: Foreign currency swap changes are shown net of reclassifications from Other comprehensive income to earnings. The amounts reclassified from Other comprehensive income resulted in a charge to earnings of $35 million for the first quarter of 2008 and an increase to earnings of $51 million for the first quarter of 2007.

4. Debt Securities

Debt Outstanding

The TVA Act authorizes TVA to issue Bonds in an amount not to exceed $30 billion at any time. Debt outstanding at December 31, 2007, and September 30, 2007, including translation losses of $264 million and $299 million, respectively, related to long-term debt denominated in foreign currencies, consisted of the following:

Debt Outstanding
	At December 31 2007			At September 30 2007
Short-term debt
Discount notes (net of discount)	$	1,565		$	1,422
Current maturities of long-term debt		2,090			90
Total short-term debt, net		3,655			1,512

Long-term debt
Long-term		19,294			21,288
Unamortized discount		(189	)		(189	)
Total long-term debt, net		19,105			21,099

Total outstanding debt	$	22,760		$	22,611

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Debt Securities Activity

The table below summarizes TVA’s long-term Bond activity for the period from October 1, 2007, to December 31, 2007.

Long-Term Bond and Note Activity

	Date	Amount		Interest Rate
Redemptions/Maturities:

electronotes®	First Quarter 2008	$	–	NA

Issuances:

electronotes®	First Quarter 2008	$	41		5.21	%

Note: electronotes® interest rate is a weighted average rate.

5. Risk Management Activities and Derivative Transactions

TVA is exposed to various market risks. These market risks include risks related to commodity prices, investment prices, interest rates, currency exchange rates, inflation, and counterparty credit risk. 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. It is TVA’s policy to enter into derivative transactions solely for hedging purposes and not for speculative purposes.

TVA has recorded the following amounts for its derivative financial instruments:

Mark-to-Market Values of Derivative Instruments


	At December 31 2007			At September 30 2007


Interest rate swap	$	(147	)	$	(115	)

Currency swaps:
Sterling		51			63
Sterling		130			148
Sterling		59			69

Swaptions:
$1 billion notional		(334	)		(269	)
$28 million notional		(4	)		(3	)
$14 million notional		(2	)		(1	)

Coal contracts with volume options		83			16

Futures and options on futures:
Margin Cash Account*		28			18
Unrealized losses		3			8

Note * In accordance with certain credit terms, TVA used leveraging to trade financial instruments under the financial trading program. 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 Financial Trading Program Activity table.

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TVA has a financial trading program under which TVA can trade futures, swaps, options on futures, and options on swaps to hedge TVA’s exposure to natural gas and fuel oil prices. At December 31, 2007, TVA had derivative positions outstanding under the program equivalent to about 3,223 contracts, made up of 2,230 futures contracts, 303 swap futures contracts, and 690 option contracts. See Derivative Positions Outstanding table below. The derivative positions outstanding under the program had an approximate net market value of $203 million at December 31, 2007. See Financial Trading Program Activity table below. For the quarter ended December 31, 2007, TVA recognized realized losses of $6 million, which were recorded as an increase to purchased power expense. Unrealized losses at December 31, 2007, were $3 million, representing a decrease of $5 million for the quarter, which TVA deferred as a regulatory asset in accordance with the FCA rate mechanism. TVA will continue to defer all financial trading program unrealized gains or losses and record only realized gains or losses as purchased power costs at the time the derivative instruments are settled.

At December 31, 2006, TVA had derivative positions outstanding under the program equivalent to about 691 contracts, made up of 691 futures contracts, zero swap futures contracts, and zero option contracts. See Derivative Positions Outstanding table below. The derivative positions outstanding under the program had an approximate net market value of $46 million at December 31, 2006. See Financial Trading Program Activity table below. For the quarter ended December 31, 2006, TVA recognized realized losses of $3 million, which were recorded as an increase to purchased power expense. Unrealized losses at the end of the quarter were $8 million, representing an increase of $2 million for the quarter, which TVA deferred as a regulatory asset in accordance with the FCA rate mechanism.

Derivative Positions Outstanding At December 31

			2007						2006
	Number of Contracts		Notional Amount per Contract (in mmBtu)		Total Notional Amount (in mmBtu)		Number of Contracts		Notional Amount per Contract (in mmBtu)		Total Notional Amount (in mmBtu)

Futures		2,230		10,000		22,300,000		691		10,000		6,910,000

Swap Futures
Exchange traded swaps (daily)		208		2,500		520,000		–		–		–
Bilateral ISDA swaps (daily)		62		20,000		1,240,000		–		–		–
Bilateral ISDA swaps (daily)		26		35,000		910,000		–		–		–
Bilateral ISDA swaps (monthly)		7		100,000		700,000		–		–		–
Subtotal		303				3,370,000		–				–

Options		690		10,000		6,900,000		–		–		–

Total		3,223				32,570,000		691				6,910,000

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Financial Trading Program Activity For the Three Months Ended December 31

	2007						2006
	Notional Amount			Contract			Notional Amount			Contract
	(in mmBtu)			Value			(in mmBtu)			Value
Futures contracts
Financial positions, beginning of period, net		16,230,000		$	131			4,290,000		$	35
Purchased		15,540,000			125			4,260,000			32
Settled		(9,470,000	)		(70	)		(1,640,000	)		(12	)
Realized (losses)		–			(6	)		–			(1	)
Net positions-long		22,300,000			180			6,910,000			54

Swap futures
Financial positions, beginning of period, net		1,970,000			12			1,822,500			11
Fixed portion		3,660,000			27			–			–
Floating portion - realized		(2,260,000	)		(14	)		(1,822,500	)		(9	)
Realized (losses)		–			–			–			(2	)
Net positions-long		3,370,000			25			–			–

Option contracts
Financial positions, beginning of period, net		5,600,000			1			–			–
Calls purchased		1,750,000			1			–			–
Puts sold		1,150,000			(1	)		–			–
Positions closed or expired		(1,600,000	)		–			–			–
Net positions-long		6,900,000			1			–			–

Holding (losses)/gains
Unrealized (loss) at beginning of period, net		–			(8	)		–			(6	)
Unrealized gains/(losses) for the period		–			5			–			(2	)
Unrealized (losses) at end of period, net		–			(3	)		–			(8	)

Financial positions at end of period, net		32,570,000		$	203			6,910,000		$	46

6. Benefit Plans

TVA sponsors a defined benefit pension plan that covers most of its full-time employees, a Supplemental Executive Retirement Plan (“SERP”) to provide additional benefits to specified individuals in addition to those available under the qualified pension plan, an unfunded postretirement medical plan that provides for non-vested contributions toward the cost of certain retirees’ medical coverage, and other postemployment benefits such as workers’ compensation.

The following table provides the components of net periodic benefit cost for the plans.

TVA Benefit Plans

	Combined			Pension			SERP		Combined			Pension			SERP		Other Benefits
	2008			2008			2008		2007			2007			2007		2008		2007
Components of net periodic benefit cost
Service cost	$	28		$	27		$	1	$	31		$	30		$	1	$	1	$	1
Interest cost		131			130			1		124			123			1		7		6
Expected return on plan assets		(152	)		(152	)		–		(143	)		(143	)		–		–		–
Amortization of prior service cost		9			9			–		9			9			–		1		1
Recognized net actuarial loss		10			10			–		20			20			–		2		2
Net periodic benefit cost	$	26		$	24		$	2	$	41		$	39		$	2	$	11	$	10

During the three months ended December 31, 2007, TVA did not make contributions to its pension plans. However, the TVA Board approved $81 million in pension contributions for 2008 with scheduled contributions of $37 million and $44 million to be made in March and September, respectively. 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 $6 million during the three months ended December 31, 2007, to fund other benefits costs.

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7. Asset Impairment

During the first quarter of 2007, TVA recognized a total of $17 million in asset impairment losses related to its Property, plant, and equipment. The $17 million Loss on asset impairment was a write-off of a scrubber project at TVA’s Colbert Fossil Plant (“Colbert”). Additional write-downs of $4 million related to other Construction in progress assets related to new pollution-control and other technologies that had not been proven effective and a re-valuation of other projects due to funding limitations were noted in the third and fourth quarters of 2007. No asset impairment has been noted through the first quarter of 2008.

8. Legal Proceedings

TVA is subject to various legal proceedings and claims that have arisen in the ordinary course of business. These proceedings and claims include the matters discussed below. In accordance with SFAS No. 5, “Accounting for Contingencies,” TVA had accrued approximately $27 million with respect to the proceedings described below as of December 31, 2007, as well as approximately $8 million with respect to other proceedings that have arisen in the normal course of TVA’s business. No assurance can be given that TVA will not be subject to significant additional claims and liabilities. If actual liabilities significantly exceed the amounts accrued, TVA’s results of operations, liquidity, and financial condition could be materially adversely affected.

Global Warming Cases. On July 21, 2004, two lawsuits were filed against TVA in the United States District Court for the Southern District of New York alleging that global warming is a public nuisance and that carbon dioxide (“CO2”) emissions from fossil-fuel electric generating facilities should be ordered abated because they contribute to causing the nuisance. The first case was filed by various states (California, Connecticut, Iowa, New Jersey, New York, Rhode Island, Vermont, and Wisconsin) and the City of New York against TVA and other power companies. The second case, which alleges both public and private nuisance, was filed against the same defendants by Open Space Institute, Inc., Open Space Conservancy, Inc., and the Audubon Society of New Hampshire. The plaintiffs do not seek monetary damages, but instead seek a court order requiring each defendant to cap its CO2 emissions and then reduce these emissions by an unspecified percentage each year for at least a decade. In September 2005, the district court dismissed both lawsuits because they raised political questions that should not be decided by the courts. The plaintiffs appealed to the United States Court of Appeals for the Second Circuit (“Second Circuit”). Oral argument was held before the Second Circuit on June 7, 2006. On June 21, 2007, the Second Circuit directed the parties to submit letter briefs by July 6, 2007, addressing the impact of the Supreme Court’s decision in Massachusetts v. EPA, 127 S.Ct. 1438 (2007), on the issues raised by the parties. On July 6, 2007, the defendants jointly submitted their letter brief.

Case Involving Alleged Modifications to the Colbert Fossil Plant. The National Parks Conservation Association, Inc. (“NPCA”), and Sierra Club, Inc. (“Sierra Club”), filed suit on February 13, 2001, in the United States District Court for the Northern District of Alabama, alleging that TVA violated the Clean Air Act (“CAA”) and implementing regulations at Colbert, a coal-fired electric generating facility located in Tuscumbia, Alabama. The plaintiffs allege that TVA made major modifications to Colbert Unit 5 without obtaining preconstruction permits (in alleged violation of the Prevention of Significant Deterioration (“PSD”) program and the Nonattainment New Source Review (“NNSR”) program) and without complying with emission standards (in alleged violation of the New Source Performance Standards (“NSPS”) program). The plaintiffs seek injunctive relief; civil penalties of $25,000 per day for each violation on or before January 30, 1997, and $27,500 per day for each violation after that date; an order that TVA pay up to $100,000 for beneficial mitigation projects; and costs of litigation, including attorney and expert witness fees. On November 29, 2005, the district court held that sovereign immunity precluded the plaintiffs from recovering civil penalties against TVA. On January 17, 2006, the district court dismissed the action, on the basis that the plaintiffs failed to provide adequate notice of NSPS claims and that the statute of limitations curtailed the PSD and NNSR claims. The plaintiffs appealed to the United States Court of Appeals for the Eleventh Circuit (“Eleventh Circuit”) on January 25, 2006. In an October 4, 2007 decision, the Eleventh Circuit affirmed dismissal of the lawsuit. In January 2008, the plaintiffs filed a petition for a writ of certiorari, asking the United States Supreme Court to hear an appeal of the Eleventh Circuit’s decision.

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Case Involving Alleged Modifications to Bull Run Fossil Plant. The NPCA and the Sierra Club filed suit against TVA on February 13, 2001, in the United States District Court for the Eastern District of Tennessee, alleging that TVA did not comply with the New Source Review (“NSR”) requirements of the CAA when TVA repaired its Bull Run Fossil Plant (“Bull Run”), a coal-fired electric generating facility located in Anderson County, Tennessee. In March 2005, the district court granted TVA’s motion to dismiss the lawsuit on statute of limitation grounds. The plaintiffs’ motion for reconsideration was denied, and they appealed to the United States Court of Appeals for the Sixth Circuit (“Sixth Circuit”). Friend of the court briefs supporting the plaintiffs’ appeal have been filed by New York, Connecticut, Illinois, Iowa, Maryland, New Hampshire, New Jersey, New Mexico, Rhode Island, Kentucky, Massachusetts, and Pennsylvania. Several Ohio utilities filed a friend of the court brief supporting TVA. Briefing of the appeal to the Sixth Circuit was completed in May 2006. Oral argument was held on September 18, 2006, and a panel of three judges issued a decision reversing the dismissal on March 2, 2007. TVA requested that the full Sixth Circuit rehear the appeal, but the Sixth Circuit denied this request. A scheduling order has been entered by the district court on remand, setting the case for trial on August 11, 2008. TVA is already installing or has installed the control equipment that the plaintiffs seek to require TVA to install in this case, and it is unlikely that an adverse decision will result in substantial additional costs to TVA at Bull Run. An adverse decision, however, could lead to additional litigation and could cause TVA to install additional emission control systems, such as scrubbers and selective catalytic reduction systems, on units where they are not currently installed, under construction, or planned to be installed. It is uncertain whether there would be significant increased costs to TVA.

Case Involving Opacity at Colbert. On September 16, 2002, the Sierra Club and the Alabama Environmental Council filed a lawsuit in the United States District Court for the Northern District of Alabama alleging that TVA violated CAA opacity limits applicable to Colbert between July 1, 1997, and June 30, 2002. The plaintiffs seek a court order that could require TVA to incur substantial additional costs for environmental controls and pay civil penalties of up to approximately $250 million. After the court dismissed the complaint (finding that the challenged emissions were within Alabama’s two percent de minimis rule, which provided a safe harbor if nonexempt opacity monitor readings over 20 percent did not occur more than two percent of the time each quarter), the plaintiffs appealed the district court’s decision to the Eleventh Circuit. On November 22, 2005, the Eleventh Circuit affirmed the district court’s dismissal of the claims for civil penalties but held that the Alabama de minimis rule was not applicable because Alabama had not yet obtained Environmental Protection Agency (“EPA”) approval of that rule. The case was remanded to the district court for further proceedings. On April 5, 2007, the plaintiffs moved for summary judgment. TVA opposed the motion and moved to stay the proceedings. On April 12, 2007, EPA proposed to approve Alabama’s de minimis rule subject to certain changes. This rulemaking proceeding is ongoing. On July 16, 2007, the district court denied TVA’s motion to stay the proceedings pending approval of Alabama’s de minimis rule. On August 27, 2007, the district court granted the plaintiffs’ motion for summary judgment, finding that TVA had violated the CAA at Colbert. The district court held that, while TVA had achieved 99 percent compliance on Colbert Units 1-4 and 99.5 percent compliance at Colbert Unit 5, TVA had exceeded the 20 percent opacity limit (measured in six-minute intervals) more than 3,350 times between January 3, 2000, and September 30, 2002. The district court ordered TVA to submit a proposed remediation plan, which TVA did on October 26, 2007. The plaintiffs have responded, and TVA’s expects the district court to decide whether or not to conduct a hearing on the matter. If EPA approves Alabama’s de minimis rule, the lawsuit will become moot.

In addition to Colbert, TVA has another coal-fired power plant in Alabama, Widows Creek Fossil Plant (“Widows Creek”), which has a winter net dependable generating capacity of 1,628 megawatts. Since the operation of Widows Creek must meet the same opacity requirements as Colbert, this plant may be affected by the decision in this case. The proposed de minimis rule change would help reduce or eliminate the chances of an adverse effect on Widows Creek from the district court decision.

Case Brought by North Carolina Alleging Public Nuisance. On January 30, 2006, North Carolina filed suit against TVA in the United States District Court for the Western District of North Carolina alleging that TVA’s operation of its coal-fired power plants in Tennessee, Alabama, and Kentucky constitute public nuisances. North Carolina is asking the court to impose caps on emissions of certain pollutants from TVA’s coal-fired plants that North Carolina considers to be equivalent to caps on emissions imposed by North Carolina law on North Carolina’s two largest electric utilities. The imposition of such caps could require TVA to install more pollution controls on a faster schedule than required by federal law. On April 3, 2006, TVA moved to dismiss the suit on grounds that the case is not suitable for judicial resolution because of separation of powers principles, including the fact that these matters are based on policy decisions left to TVA’s discretion in its capacity as a government agency and thus are not subject to tort liability (the “discretionary function doctrine”), as well as the Supremacy Clause. In July 2006, the court denied TVA’s motion and set the trial for the term of court beginning October 2007. On August 4, 2006, TVA filed a motion requesting permission to file an interlocutory appeal with the United States Court of Appeals for the Fourth Circuit (the “Fourth Circuit”), which the district court granted on September 7, 2006. On September 21, 2006, TVA petitioned the Fourth Circuit to allow the interlocutory appeal. The Fourth Circuit granted the petition, but the district court did not stay the case during the appeal. Briefing of the interlocutory appeal to the Fourth Circuit was completed in January 2007, and oral argument was held on October 31, 2007. On July 2, 2007, North Carolina filed with the district court a motion for partial summary judgment addressing certain of TVA’s defenses. On July 31, 2007, and August 20, 2007, TVA filed two separate motions for summary judgment, seeking dismissal of the lawsuit. The trial before the district court previously scheduled for the term of court beginning October 2007 has been canceled and has not yet been rescheduled. On January 31, 2008, the Fourth Circuit affirmed the denial of TVA’s motion to dismiss. TVA has not yet decided whether to seek a rehearing before the full Fourth Circuit.

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Case Involving North Carolina’s Petition to the EPA. In 2005, the State of North Carolina petitioned the EPA under Section 126 of the CAA to impose additional emission reduction requirements for sulfur dioxide (“SO2”) and nitrogen oxides (“NOx”) emitted by coal-fired power plants in 13 states, including states where TVA’s coal-fired power plants are located. In March 2006, the EPA denied the North Carolina petition primarily on the basis that the Clean Air Interstate Rule remedies the problem. In June 2006, North Carolina filed a petition for review of EPA’s decision with the United States Court of Appeals for the District of Columbia Circuit. On October 1, 2007, TVA filed a friend of the court brief in support of EPA’s decision to deny North Carolina’s Section 126 petition.

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 residents of Mississippi 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, including TVA and other utilities. The plaintiffs allege that the defendants’ greenhouse gas emissions contributed to global warming and were a proximate and direct cause of Hurricane Katrina’s increased destructive force. The plaintiffs are seeking monetary damages among other relief. TVA has moved to dismiss the complaint on grounds that TVA’s operation of its coal-fired plants is not subject to tort liability due to the discretionary function doctrine. On August 30, 2007, the district court heard oral arguments on whether the issue of greenhouse gas emissions is a political matter which should not be decided by the court. The district court then dismissed the case on the grounds that the plaintiffs lacked standing. The dismissal has been appealed to the United States Court of Appeals for the Fifth Circuit.

East Kentucky Power Cooperative Transmission Case. In April 2003, Warren Rural Electric Cooperative Corporation (“Warren”) notified TVA that it was terminating its TVA power contract. Warren then entered into an arrangement with East Kentucky Power Cooperative, Inc. (“East Kentucky”) under which Warren would become a member of East Kentucky, and East Kentucky would supply power to Warren after its power contract with TVA expires in 2009. East Kentucky then asked TVA to provide transmission service to East Kentucky for its service to Warren. TVA denied the request on the basis that, under the anti-cherrypicking provision, it was not required to provide the requested transmission service. East Kentucky then asked to interconnect its transmission system with the TVA transmission system in three places that are currently delivery points through which TVA supplies power to Warren. TVA did not agree and East Kentucky asked the Federal Energy Regulatory Commission (“FERC”) to order TVA to provide the interconnections. In January 2006, FERC issued a final order directing TVA to interconnect its transmission facilities with East Kentucky’s system at three locations on the TVA transmission system. On August 11, 2006, TVA filed an appeal in the U.S. Court of Appeals for the District of Columbia Circuit seeking review of this order on the grounds that this order violated the anti-cherrypicking provision. On January 10, 2007, TVA and Warren executed an agreement under which Warren rescinded its notice of termination. On May 3, 2007, East Kentucky filed a motion with FERC to terminate the FERC proceeding on grounds of mootness. TVA has also filed a motion with FERC to vacate all orders issued in the proceeding. On December 12, 2007, FERC granted the motion to terminate the proceeding, but denied the motion to vacate its previous orders.

Case Involving Areva Fuel Fabrication. On November 9, 2005, TVA received two invoices totaling $76 million from Framatome ANP Inc., which subsequently changed its name to AREVA NP Inc. (“AREVA”). AREVA asserted that it was the successor to the contract between TVA and Babcock and Wilcox Company (“B&W”) under which B&W would provide fuel fabrication services for TVA’s Bellefonte Nuclear Plant. AREVA’s invoices were based upon the premise that the contract required TVA to buy more fuel fabrication services from B&W than TVA actually purchased. In September 2006, TVA received a formal claim from AREVA which requested a Contracting Officer’s decision pursuant to the Contract Disputes Act of 1978 and reduced the amount sought to approximately $25.8 million. On April 13, 2007, the Contracting Officer issued a final decision denying the claim. On April 19, 2007, AREVA filed suit in the United States District Court for the Eastern District of Tennessee, reasserting the $25.8 million claim and alleging that the contract required TVA to purchase certain amounts of fuel and/or to pay a cancellation fee. TVA filed its answer to the complaint on June 15, 2007. AREVA subsequently raised its claim to $47.9 million. Trial is scheduled to begin September 29, 2008.

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Notification of Potential Liability for Ward Transformer Site. EPA and a working group of potentially responsible parties (“PRPs”) have provided documentation showing that TVA sent electrical equipment containing PCBs to the Ward Transformer site in Raleigh, North Carolina. Under the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), any entity which arranges for disposal of a CERCLA hazardous substance at a site may bear liability for the cost of cleaning up the site. The working group is cleaning up on-site contamination in accordance with an agreement with EPA and plans to sue non-participating PRPs for contribution. The estimated cost of the cleanup is $20 million. In addition, EPA likely has incurred several million dollars in response costs, and the working group has reimbursed EPA approximately $725,000 of those costs. EPA has also proposed a cleanup plan for off-site contamination. The present worth cost estimate for performing the proposed plan is about $5 million. In addition, there may be natural resource damages liability related to this site, but TVA is not aware of any estimated amount for any such damages.

Completion of Browns Ferry Unit 1, Team Incentive Fee Pool Claims. Under the contracts for the restart of TVA’s Browns Ferry Unit 1, the engineering and construction contractors, Bechtel Power Corporation and Stone & Webster Construction, Inc., respectively, are to share in a team incentive fee pool funded from cost savings for the respective workscopes. The contracts provide that each contractor’s maximum payment from this pool will be as much as $38 million, for a maximum total payout under both contracts of $76 million. The contractors have taken the position that they should each receive the maximum payment. Currently, TVA has calculated each contractor’s share at $12,371,405, for a total payout under both contracts of $24,742,810. TVA and the contractors have agreed to nonbinding mediation of the matter. It is reasonably possible that TVA could incur some potential liability in excess of the amount previously calculated, but TVA is unable to estimate any such amount at this time.

Notice of Violation at Widows Creek Unit 7. On July 16, 2007, TVA received a Notice of Violation (“NOV”) from EPA as a result of TVA’s failure to properly maintain ductwork at Widows Creek Unit 7. From 2002 to 2005, the unit’s ducts allowed SO2 and NOx to escape into the air. TVA repaired the ductwork in 2005, and the problem has been resolved. TVA is reviewing the NOV. While the NOV does not set out an administrative penalty, it is likely that TVA will face a monetary sanction through giving up emission allowances, paying an administrative penalty, or both. TVA's estimate of potential monetary sanctions is included in the accrued amount listed above.

Paradise Fossil Plant Clean Air Act Permit. On December 21, 2007, the Sierra Club, the Center for Biological Diversity, Kentucky Heartwood, and Hilary Lambert filed a petition with the EPA raising objections to the conditions of TVA’s current Clean Air Act permit at the Paradise Fossil Plant (“Paradise”). Among other things, the petitioners allege that activities at Paradise triggered the NSR requirements for NOx and that the monitoring of opacity at Units 1 and 2 of the plant is deficient. The current permit continues to remain in effect. It is unclear whether or how the plant’s permit might be modified as a result of this proceeding.

Employment Proceedings. TVA is engaged in various administrative and legal proceedings arising from employment disputes. These matters are governed by federal law and involve issues typical of those encountered in the ordinary course of business of a utility. They may include allegations of discrimination or retaliation (including retaliation for raising nuclear safety or environmental concerns), wrongful termination, and failure to pay overtime under the Fair Labor Standards Act. Adverse outcomes in these proceedings would not normally be material to TVA’s results of operations, liquidity, and financial condition, although it is possible that some outcomes could require TVA to change how it handles certain personnel matters or operates its plants.

Significant Litigation to Which TVA Is Not a Party. On April 2, 2007, the Supreme Court issued an opinion in the case of United States v. Duke Energy, vacating the ruling of the Fourth Circuit in favor of Duke Energy and against EPA in EPA’s NSR enforcement case against Duke Energy. The NSR regulations apply primarily to the construction of new plants but can apply to existing plants if a maintenance project (1) is “non-routine” and (2) increases emissions. The Supreme Court held that the test for emission increases under the NSR program does not have to be the same as the test under EPA’s New Source Performance Standard program. In light of the decision it appears that under EPA’s PSD regulations, increases in annual emissions should be used for the test, not hourly emissions as utilities, including TVA, have argued should be the standard. Annual emissions can increase when a project improves the reliability of plant operations and, depending on the time period over which emission changes are calculated, it is possible to argue that almost all reliability projects increase annual emissions. Neither the Supreme Court nor the Fourth Circuit addressed what the “routine” project test should be. The United States District Court for the Middle District of North Carolina had ruled for Duke on this issue, holding that “routine” must take into account what is routine in the industry and not just what is routine at a particular plant or unit as EPA has argued. EPA did not appeal this ruling. On October 5, 2007, EPA filed a motion with the United States District Court for the Middle District of North Carolina asking that court to vacate its entire prior ruling, including the portion relating to the test for “routine” projects.

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TVA is currently involved in two NSR cases (one involving Bull Run, the dismissal of which was recently reversed on appeal) and another at Colbert (the dismissal of which was recently affirmed on appeal but may be reviewed by the U.S. Supreme Court). These cases are discussed in more detail above. The Supreme Court’s holding could undermine one of TVA’s defenses in these cases, although TVA has other available defenses. Environmental groups and North Carolina have given TVA notice in the past that they may sue TVA for alleged NSR violations at a number of TVA units. The Supreme Court’s decision could encourage such suits, which are likely to involve units where emission control systems such as scrubbers and selective catalytic reduction systems are not installed, under construction, or planned to be installed in the relatively near term.

9. Subsequent Events

Debt

In January 2008, TVA issued a total of $500 million in power bonds with a coupon of 4.875 percent. The bonds have a final maturity of January 2048.

In January 2008, TVA announced it will redeem three of its electronotes® issues on February 15, 2008. TVA will redeem all $25 million outstanding of its 2001 six percent electronotes® due December 15, 2021, all $28 million outstanding of its 2002 5.5 percent electronotes® due August 15, 2022, and all $4 million outstanding of its 2006 5.625 percent electronotes® due August 15, 2016. Each of these issues will be redeemed at 100 percent of par value.

In January 2008, TVA issued $36 million of electronotes® with an interest rate of 4.75 percent which mature in 2028 and are callable beginning in 2012.

In February 2008, TVA announced it will redeem two of its electronotes® issues on March 11, 2008. TVA will redeem all $28 million outstanding of its 2002 6.125 percent electronotes® due January 15, 2022, and all $13 million outstanding of its 2002 6.125 percent electronotes® due April 15, 2022. Each of the issues of electronotes® will be redeemed at 100 percent of par value.

TVA monetized the call options on two public bond issues by entering into two swaption transactions (see Note 10, Risk Management Activities and Derivative Transactions in Part II of the 2007 Form 10-K). In February 2008, the counterparty to the swaption transactions exercised its options to enter into swaps with TVA, effective March 11, 2008, where TVA will be required to make fixed rate payments to the counterparty of 6.125 percent and the counterparty will be required to make floating payments to TVA based on London Interbank Offered Rate (“LIBOR”). These payments will be based on a combined notional amount of $41.7 million and will begin on April 15, 2008.

Properties

On December 14, 2007, TVA entered into an agreement to purchase the Office of Power Complex (the portion of TVA's Chattanooga Office Complex in Chattanooga, Tennessee, leased from Chattanooga Valley Associates) upon the expiration of the existing lease on January 1, 2011. The purchase price is $22 million, payable on January 3, 2011.

Regulation of Mercury

On February 8, 2008, the United States Circuit Court for the District of Columbia (the “D.C. Circuit”) vacated EPA’s Clean Air Mercury Rule (“CAMR”). CAMR established caps for overall mercury emissions in two phases, with the first phase becoming effective in 2010 and the second in 2018. It allowed the states to regulate mercury emissions through a market-based cap-and-trade program. All of the states in which TVA operates potentially affected sources adopted CAMR without significant change. TVA is currently evaluating the potential impact of the D.C. Circuit’s decision on its operations. It is possible that TVA may incur higher costs in the future should a replacement of, or significant modification to, CAMR impose increased regulatory restrictions and the need for additional environmental controls or a change in the way TVA operates its facilities. See Item 1, Business — Environmental Matters in the Annual Report.

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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 TVA. The MD&A should be read in conjunction with the accompanying financial statements and TVA’s Annual Report on Form 10-K, as amended, for the fiscal year ended September 30, 2007 (the “Annual Report”).

Business Overview

Financial Outlook

Net income for the three months ended December 31, 2007, was $8 million compared to net income of $70 million for the same period of 2006. This change was primarily due to changes in ratemaking methodology related to capitalized interest on construction projects (“AFUDC”) resulting in additional expense of $46 million. Additionally, TVA changed its ratemaking methodology for gains and losses on certain derivative instruments used in call monetization transactions which increased income by $15 million in the first quarter of 2006. See Results of Operations.

TVA still faces challenges related to fuel, purchased power, hydroelectric generation, and capacity during the remainder of the year. Long-term demand projections indicate upward pressure on capacity and the need for additional capacity to be built or purchased over TVA's planning horizon. TVA is discussing the possibility of a rate increase with the Tennessee Valley Public Power Association, Inc. (“TVPPA”), a group that represents most of TVA’s distributor customers, and with other groups. The increase could be between six and nine percent and is expected to be implemented in April 2008 if approved by the TVA Board of Directors (“TVA Board”). In addition to funding additional capacity and other capital projects, the adjustment would help ensure that TVA collects revenues needed to meet the requirements of the TVA Act and the tests and provisions of its bond resolutions, and do so in accordance with the financial objectives set forth in the Strategic Plan adopted by the TVA Board on May 31, 2007 (the “Strategic Plan”). Based upon the calculation methods in use as of December 31, 2007, it was anticipated that the rate increase would generate an additional $265 million to $400 million of revenue during 2008 depending on the percentage increase approved by the TVA Board.

Fuel-Cost Adjustment

As of December 31, 2007, TVA had recognized a regulatory asset of $117 million representing deferred fuel and purchased power costs to be recovered through the fuel cost adjustments (“FCA”) in future periods. The current portion of the asset to be collected within the next 12 months is $102 million and is held as a current asset in accounts receivable. The remaining long term portion of $15 million is held as a regulatory asset. Under TVA’s FCA methodology, adjustments to rates are based on the difference between forecasted and baseline (budgeted) costs for the upcoming quarter. Because the FCA adjustments are forward-looking, there is typically a difference between what is collected in rates and what actual expense is realized over the course of the quarter. This difference is added to or deducted from certain accounts on TVA’s balance sheet. The higher or lower costs added to or taken away from the balance sheet accounts are then amortized to expense in the periods in which they are to be collected in revenues. This methodology allows better matching of the revenues with associated expenses. The FCA amount to be implemented January 1, 2008, is 0.267 cents per kilowatt-hour. Based upon the FCA calculation methodology in use as of January 1, 2008, the FCA was expected to produce an estimated $105 million in revenue during the second quarter of 2008. See Note 1 — Accounts Receivables and Cost-Based Regulation.

Weather Conditions

The amount of electricity that TVA is able to generate from its hydroelectric plants depends on a number of factors outside TVA's control, including the amount of precipitation, runoff, initial water levels, the need for water for competing water-management objectives, and the availability of its hydroelectric generation plants. When these factors are unfavorable, TVA must increase its reliance on more expensive generation plants and purchased power. TVA continued to be impacted by drought conditions during the first quarter of 2008. Although rainfall totals from October 1, 2007, through January 31, 2008, were 72 percent of normal, runoff totals were far less at 33 percent of normal. Reduced hydroelectric generation has driven up purchased-power costs, which were about $40 million higher than projected for the first quarter of 2008.

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Performance of TVA Assets

Unscheduled Outage. Browns Ferry Nuclear Plant Unit 3 had an automatic shutdown of its nuclear reactor on December 31, 2007. The shutdown was determined to be caused when the main turbine generator received a load reject signal. A load reject signal causes the system to “think” that the generator has lost the attached load. All safety systems responded properly to the signal. The unit was returned to service on January 21, 2008. The net cost of the repair is estimated to be less than $3 million and the cost of replacement power during this period was $33 million. The cost of this replacement power will be recovered through the FCA.

Extended Outage. The duration of a planned outage scheduled from October 3, 2007, to November 2, 2007, at Sequoyah Nuclear Plant Unit 1 was extended 16 days due to the identification of damage in the main generator during the outage work. The cost of additional work related to the generator was $7 million and the net cost of replacement power during this extended period was $22 million. The cost of this replacement power will be recovered through the FCA.

Challenges Related to Water Supply and Water Temperature

TVA faces challenges related to water supply and water temperature on the Cumberland River where the U.S. Army Corps of Engineers (“Corps”) operates hydroelectric facilities and TVA operates fossil plants and on the Tennessee River System where TVA operates hydroelectric facilities, fossil plants, and nuclear plants.

Cumberland River Challenges. The Corps operates eight hydroelectric facilities on the Cumberland River. Of these facilities, Wolf Creek Dam and Center Hill Dam are in need of emergency repairs. The need to repair the dams and the drought in the southeast has resulted in less water flow and high water temperature. There have been two effects on TVA.

The first is a reduction in the amount of power TVA receives from the Southeastern Power Administration (“SEPA”). TVA, along with others, has contracted with SEPA for the power produced from the Corps’s Cumberland River hydroelectric facilities. Under the contract, SEPA was to provide TVA an annual minimum of 1,500 hours of power for each megawatt of TVA's 405 megawatt allocation, and all surplus power from the Corps’s hydroelectric facilities on the Cumberland River. As a result of the need the repair to Wolf Creek and Center Hill dams and as a result of the drought, SEPA has instituted an emergency operation plan that:

•

Eliminates its obligation to provide TVA (and any affected customer) with a minimum amount of power;

•

Provides for all affected customers (except TVA) to receive a specified share of a portion of the gross hourly generation from the eight Cumberland River hydroelectric facilities, with TVA receiving the remainder;

•

Eliminates the payment of demand charges by customers (including TVA) since there is significantly reduced dependable capacity on the Cumberland River system; and

•

Increases the rate charged per kilowatt-hour of energy received by SEPA's customers (including TVA).

It is likely that the end of the drought will not eliminate the need for the emergency operating plan. It is unclear how long it will take the Corps to repair these facilities and how long the emergency operating plan will remain in effect.

The second is the likelihood that TVA will have to reduce power output (“derate”) its Cumberland and Gallatin Fossil Plants at times during the summer. During the summer of 2007, the temperature of the Cumberland River reached the point where TVA had to derate these plants in order not to exceed thermal limits. Future summer derates remain a possibility until the Wolf Creek and Center Hill dams are repaired and normal water flow is restored on the Cumberland River.

Tennessee River System Challenges. The drought in the southeast has resulted in less rainfall in the area drained by the Tennessee River and its tributaries and less runoff into the system. This results in there being less water available for cooling purposes and the available water having a higher temperature. In order not to exceed thermal limits, during the summer of 2007 TVA derated two fossil plants and at Browns Ferry Nuclear Plant, temporarily took one unit offline and reduced the output at the other two units. Additionally, TVA used its cooling towers at Browns Ferry and Sequoyah Nuclear Plants. Using the cooling towers takes a substantial amount of power that TVA would have otherwise sold. If the drought continues, TVA may have to take similar actions in the summer of 2008

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Meeting the Power Needs in TVA’s Service Area

Combined Cycle Facility. TVA completed the acquisition of a combined cycle facility located in southwest Tennessee in October 2007. Now known as Lagoon Creek 3, the unfinished site contains turbine foundations and substantial ancillary equipment. With an anticipated commercial operation date of June 2010, the facility is expected to have a planned winter net dependable capacity of approximately 600 megawatts.

New Nuclear Generation. TVA submitted its combined license application to the Nuclear Regulatory Commission ("NRC") for Bellefonte Nuclear Plant Units 3 and 4 in October 2007. If approved, the license to build and operate the plant would be issued to TVA. Obtaining the necessary license would give TVA more certainty about the cost and schedule of a nuclear option for future decisions. The combined license application for two AP1000 reactors at Bellefonte was officially docketed by the NRC on January 18, 2008, indicating the NRC found it complete and technically sufficient to support their more detailed reviews. The TVA Board has not made a decision to construct a new plant at the Bellefonte site, and TVA continues to evaluate all nuclear generation options at the site.

Preliminary project activities began at Watts Bar Nuclear Plant Unit 2 in October 2007. TVA began to engage in unrestricted construction activities at the end of December 2007, having previously notified the NRC that such activities may begin after December 3, 2007. When completed, Watts Bar Unit 2 is expected to provide 1,180 megawatts of capacity.

Purchased Power. Purchasing power from others will likely remain a part of how TVA meets the power needs of its service area. The Strategic Plan establishes a goal of balancing production capabilities with power supply requirements within five percent. Achieving this goal will allow TVA to reduce its reliance on purchased power, which constituted over 14 percent of the power that TVA sold to its customers in the first quarter of 2008. The purchases during the first quarter of 2008 represent a 41 percent increase over the amount of power purchased during the first quarter of 2007. However, TVA forecasts that purchased power volume as a percentage of total system requirements will likely be less in 2008 than 2007. See Performance of TVA Assets.

TVA intends to consider other opportunities to add new generation from time to time. Market conditions, like the volatility of the price of construction materials and the potential shortage of skilled craft labor, may add uncertainties to the cost and schedule of new construction.

Customers

On January 1, 2008, Bristol Virginia Utilities (“BVU”) became the 159th municipal supplier or electric cooperative to connect with TVA’s power grid. The new contract has a minimum 15-year term, and a five-year termination notice may not be given until January 2018. The rates under this contract are intended to recover the cost of reintegrating BVU into TVA’s power-supply plan and serving its customer load. BVU is a 16,000-customer distributor that was previously served by TVA from 1945 to 1997, and sales to BVU accounted for approximately 0.4 percent of TVA’s annual operating revenues in 1997. Sales to BVU are forecasted to remain approximately 0.4 percent of TVA’s total sales.

Service Reliability

TVA met a monthly peak demand record on October 8, 2007, of 28,601 megawatts, which was 12.3 percent higher than the prior record set in October 2006. A record peak was also set for the month of November 2007 with 25,280 megawatts, exceeding the 25,169 megawatt record set in November 2006. This was the fourth consecutive monthly record peak load.

On January 25, 2008, TVA met a record winter demand of 32,027 megawatts without any customer interruptions. During the hour of peak supply, purchased power constituted approximately 12 percent of TVA's load.

TVA hosted a formative meeting of regional transmission planning stakeholders for the Central Region Public Power Partners, which includes Associated Electric Cooperative, Inc., Big Rivers EC, East Kentucky Power Cooperative, and TVA. Stakeholders participating included TVPPA, as well as representatives of independent power producers, utility marketing organizations, peer transmission planners, and the Kentucky Public Service Commission. This new planning and stakeholder process is another step in TVA's efforts to better coordinate TVA transmission operations with neighboring systems and to involve stakeholder groups in the planning of TVA's bulk transmission facilities. The stakeholder process is being voluntarily implemented by TVA as part of TVA's effort to comply with Federal Energy Regulatory Commission's (“FERC”) Order 890, which revises the FERC pro-forma tariff applicable to jurisdictional public utilities.

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Liquidity and Capital Resources

Sources of Liquidity

TVA’s current liabilities exceed current assets because of the continued use of short-term debt to fund cash needs as well as scheduled maturities of long-term debt. To meet short-term cash needs and contingencies, TVA depends on various sources of liquidity. TVA’s primary sources of liquidity are cash on hand and cash from operations, proceeds from the issuance of short-term and long-term debt, and proceeds from borrowings under TVA’s $150 million note with the U.S. Treasury. Other sources of liquidity include two $1.25 billion credit facilities with a national bank and occasional proceeds from other financing arrangements including call monetization transactions and sales of receivables and loans.

The majority of TVA’s balance of cash on hand is typically invested in short-term investments. During 2007, TVA’s average daily balance of cash and cash equivalents on hand was $389 million. The daily balance of cash and cash equivalents maintained is based on near-term expectations for cash expenditures and funding needs. TVA’s cash and cash equivalents at December 31, 2007, was $158 million, a decrease of $7 million from the cash balance at September 30, 2007.

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 quarters ended December 31, 2007, and 2006, follows:

Summary Cash Flows

For the Three Months Ended December 31

	2007			2006
	As Restated			As Restated
Cash provided by (used in)
Operating activities	$	302		$	389
Investing activities		(482	)		(534	)
Financing activities		173			111
Net decrease in cash and cash equivalents	$	(7	)	$	(34	)

Issuance of Debt. TVA issued $41 million of power bonds during the three months ended December 31, 2007. Subsequent to December 31, 2007, TVA issued $500 million of power bonds and $36 million of electronotes®. No long-term debt was retired or redeemed during this period. For more information about TVA's debt activities, see Notes 4 and 9.

Credit Facilities. In the event of shortfalls in cash resources, TVA has short-term funding available in the form of two $1.25 billion short-term revolving credit facilities, one of which matures on May 14, 2008, and the other of which matures on November 10, 2008. The interest rate on any borrowing under either of these facilities is variable and 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 against which TVA has not borrowed. The fee may fluctuate depending on the non-enhanced credit ratings on TVA’s senior unsecured long-term debt. There were no outstanding borrowings under the facilities at December 31, 2007. TVA anticipates renewing each credit facility from time to time.

Comparative Cash Flow Analysis

2008 Compared to 2007

Net cash provided by operating activities decreased $87 million from $389 million to $302 million for the three months ended December 31, 2006, and 2007, respectively. This decrease resulted from:

•

An increase in cash used by changes in working capital of $121 million resulting primarily from a larger increase in inventories and other of $25 million and a $145 million greater reduction in accounts payable and accrued liabilities, partially offset by a $42 million greater decrease in accounts receivable and a $7 million smaller reduction in interest payable;

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•

An increase in cash paid for fuel and purchased power of $118 million due to higher volume and increased market prices for purchased power;

•

An increase in cash paid for interest of $39 million;

•

An increase in cash outlays for routine and recurring operating costs of $35 million; and

•

An increase in tax equivalent payments of $13 million.

These items were partially offset by an increase in operating revenues of $245 million resulting primarily from increases in revenue from municipalities and cooperatives and industries directly served, in both cases, from higher average rates and the FCA and, in the case of industries directly served, higher volume.

Cash used in investing activities decreased $52 million from the first quarter of 2007 to the first quarter of 2008. The decrease is primarily due to:

•

The inclusion in the first quarter of 2007 of a $98 million use of funds to acquire two combustion turbine facilities;

•

A $23 million reduction in the amount of restricted cash and investments held by TVA during the first quarter of 2008 compared to an $8 million increase in the amount of restricted cash and investments held by TVA during the same period of 2007; and

•

A decrease in expenditures for capital projects of $33 million.

These items were partially offset by an increase in expenditures for the enrichment and fabrication of nuclear fuel of $104 million related to a buildup of fuel for strategic inventory, fuel for identified upcoming Browns Ferry Nuclear Unit 3 and Watts Bar Nuclear Unit 1 outages, and blended low enriched uranium fuel and uranium purchases that are not identified to a specific outage. The effect of these increases was somewhat offset by reductions of fuel inventory for fuel loaded into the reactor at Browns Ferry.

Net cash provided by financing activities was $62 million higher for the three months ended December 31, 2007, compared to the same quarter of the prior year. The increase was primarily due to:

•

A decrease in redemptions and repurchases of long-term debt of $77 million, with no long-term debt retired in the first quarter of 2008; and

•

An increase in long-term debt issues of $32 million as a result of the issuance of $41 million of long-term debt.

These items were partially offset by a decrease in net issuances of short-term debt of $47 million in the first quarter of 2008 compared to the same quarter of the prior year.

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Cash Requirements and Contractual Obligations

The estimated cash requirements and contractual obligations for TVA as of December 31, 2007, are detailed in the following table.

Commitments and Contingencies

	Total			2008 (1)		2009		2010		2011		2012		Thereafter

Debt	$	22,685	(2)	$	1,655	$	2,031	$	62	$	1,015	$	1,525	$	16,397
Interest payments relating to debt		20,724			838		1,228		1,120		1,089		1,060		15,389
Lease obligations
Capital		180			30		58		57		29		3		3
Non-cancelable operating		411			47		50		39		29		27		219
Purchase obligations
Power		5,929			175		221		237		242		248		4,806
Fuel		3,136			982		557		528		220		258		591
Other		658			239		212		32		28		27		120
Payments on other financings		1,467			83		85		89		95		97		1,018
Payment to U.S. Treasury (3)
Return of Power Facilities Appropriation Investment		130			20		20		20		20		20		30
Return on Power Facilities Appropriation Investment		258			19		22		21		20		18		158
Retirement plans (4)		81			81		–		–		–		–		–
Total	$	55,659		$	4,169	$	4,484	$	2,205	$	2,787	$	3,283	$	38,731

Notes

(1)

Period January 1 - September 30, 2008.

(2)

Does not include noncash items of foreign currency valuation loss of $264 million and net discount on sale of Bonds of $189 million.

(3)

TVA has access to financing arrangements with the U.S. Treasury whereby the U.S. Treasury is authorized to accept from TVA a short-term note with the maturity of one year or less in an amount not to exceed $150 million. TVA may draw any portion of the authorized $150 million during the year. TVA’s practice is to repay on a quarterly basis the outstanding balance of the note and related interest. Because of this practice, there was no outstanding balance on the note as of December 31, 2007. Accordingly, the Commitments and Contingencies table does not include any outstanding payment obligations to the U.S. Treasury for this note at December 31, 2007.

(4)

TVA’s Board plans to evaluate the need for future funding on an annual basis through the ratemaking process.

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

Energy Prepayment Obligations

	Total		2008 (1)		2009		2010		2011		2012		Thereafter

Energy Prepayment Obligations	$	1,112	$	79	$	105	$	105	$	105	$	105	$	613

Note

(1)

Period January 1 - September 30, 2008.

During the first quarter of 2008, TVA executed certain contracts related to the resumption of construction activities at Watts Bar Nuclear Plant Unit 2. As of December 31, 2007, expenditures against these contracts are forecasted to be approximately $1.2 billion.

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Results of Operations

Financial Results

The following table compares operating results and selected statistics for the three months ended December 31, 2007, and 2006:

Summary Statements of Income

For the Three Months Ended December 31

	2007			2006
	As Restated			As Restated
Operating revenues	$	2,360		$	2,126
Operating expenses		(2,012	)		(1,785	)
Operating income		348			341
Other income		3			18
Unrealized gain on derivative contracts, net		–			15
Interest expense, net		(343	)		(304	)
Net income	$	8		$	70

Sales (millions of kWh)		42,735			40,918

Heating degree days (normal 1,311)		1,058			1,227
Cooling degree days (normal 64)		150			63
Combined degree days (normal 1,375)		1,208			1,290

Net income for the three months ended December 31, 2007, was $8 million compared to net income of $70 million for the same period in 2006. The $62 million change in net income was primarily attributable to:

•

A $227 million increase in operating expenses;

•

A $39 million increase in net interest expense resulting primarily from a change in ratemaking methodology relating to AFUDC;

•

A $15 million decrease in net unrealized gain on derivative contracts resulting primarily from a change in ratemaking methodology for gains and losses on certain derivative instruments used in call monetization transactions; and

•

A $15 million decrease in other income.

These items were partially offset by a $234 million increase in operating revenues.

Operating Revenues. Operating revenues and sales of electricity for the three months ended December 31, 2007, and 2006, consisted of the following:

Operating Revenues and Sales of Electricity For the Three Months Ended December 31

	Operating Revenues							Sales of Electricity
	(millions of dollars)							(millions of kWh)
	2007		2006		Percent Change			2007		2006		Percent Change
	As Restated		As Restated					As Restated		As Restated
Sales of Electricity
Municipalities and cooperatives	$	1,913	$	1,763		8.5	%		32,476		32,310		0.5	%
Industries directly served		392		302		29.8	%		9,818		8,108		21.1	%
Federal agencies and other		25		25		0.0	%		441		500		(11.8	%)
Other revenue		30		36		(16.7	%)		–		–		–

Total	$	2,360	$	2,126		11.0	%		42,735		40,918		4.4	%

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Significant items contributing to the $234 million increase in operating revenues included:

•

A $150 million increase in revenue from municipalities and cooperatives primarily due to the FCA, which provided $131 million in additional revenues. Fluctuations in rates related to certain types of energy programs and credits, and a slight increase in sales of less than one percent provided $10 million and $9 million, respectively, in additional revenues; and

•

A $90 million increase in revenue from industries directly served primarily attributable to increased sales of 21.1 percent, the FCA and fluctuations in rates related to certain types of energy programs and credits. Increased sales, the FCA, and fluctuations in rates related to certain types of energy programs and credits yielded $61 million, $18 million, and $11 million, respectively, in additional revenue.

These items were partially offset by a $6 million decrease in other revenue primarily due to decreased revenue from salvage sales and a gain on the sale of sulfur dioxide (“SO2”) emission allowances during the first quarter of 2007 not present in the first quarter of 2008.

Significant items contributing to the 1,817 million kilowatt-hour increase in electricity sales for the first quarter of 2008 compared to the same period in 2007 include the following:

•

A 1,710 million kilowatt-hour increase in sales to industries directly served. This was mainly attributable to increased demand from TVA’s largest and second largest directly served industrial customers of 24.2 percent and 82.2 percent, respectively, to accommodate higher production levels at their facilities. In addition, aggregate demand from a few other large directly served industrial customers increased 26.0 percent as a result of changes in product mix and higher production levels at their facilities.

•

A 166 million kilowatt-hour increase in sales to municipalities and cooperatives due to an increase in aggregate sales to commercial and industrial customers.

These increases were partially offset by:

•

A 59 million kilowatt-hour decrease in sales to Federal agencies and other.

This decrease was due to an 86 million kilowatt-hour decrease in off-system sales mainly reflecting decreased generation available for sale.

The decrease in off-system sales was partially offset by a 27 million kilowatt-hour increase in sales to directly served federal agencies largely attributable to an increase in demand by several directly served federal agencies as a result of a change in the nature and scope of their loads.

Operating Expenses. Operating expenses for the three months ended December 31, 2007, and 2006, consisted of the following:

Operating Expenses For the Three Months Ended December 31

	2007		2006		Percent Change
	As Restated		As Restated

Fuel and purchased power	$	922	$	749		23.1	%
Operating and maintenance		580		550		5.5	%
Depreciation, amortization, and accretion		390		361		8.0	%
Tax equivalents		120		108		11.1	%
Loss on asset impairment		–		17		(100.0	%)
Total operating expenses	$	2,012	$	1,785		12.7	%

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Significant drivers contributing to the $227 million increase in total operating expenses included:

•

A $173 million increase in Fuel and purchased power expense.

This increase was due to a $144 million increase in purchased power expense and a $29 million increase in fuel expense.

–

The increase in purchased power expense resulted from:

•

An increase in the average purchase price of 20.4 percent, which resulted in $77 million in additional expense;

•

An increase in the volume of purchased power of 40.7 percent, which resulted in $55 million in additional expense; and

•

A decrease in the FCA net deferral and amortization for purchased power expense of $12 million.

–

The increase in fuel expense resulted from:

•

An increase in the net commercial generation of 7.7 percent, which resulted in $43 million in additional expense; and

•

A decrease in the FCA net deferral and amortization for fuel expense of $29 million.

–

The increase in fuel expense was partially offset by a 7.0 percent lower aggregate fuel cost per kilowatt-hour net thermal generation, which reduced fuel expense by $43 million.

•

A $29 million increase in Depreciation, amortization, and accretion expense.

This increase was a result of a $29 million increase in depreciation expense due to:

–

An increase in depreciation rates at several of TVA’s facilities; and

–

An increase in completed plant accounts due to net plant additions.

•

A $30 million increase in Operating and maintenance expense.

This increase was mainly a result of:

–

Increased outage and routine operating and maintenance costs at coal-fired plants of $26 million largely due to:

•

An increase in outage days of 173 days as a result of one more planned outage and a change in the nature and scope of the outages during the first quarter of 2008;

•

Significant repair work on Unit 3 at Paradise Fossil Plant not present in the first quarter of 2007; and

•

The operation of two additional combustion turbine units not operated during the first quarter of 2007; and

–

Increased routine operating and maintenance costs at nuclear plants of $19 million primarily attributable to:

•

The operation of an additional nuclear unit not operated in the first quarter of 2007;

•

Timing of contractor work and materials purchased; and

•

Timing of mid-cycle and forced outages.

These items were partially offset by:

–

Decreased pension costs of $15 million mainly as a result of a 0.35 percent higher discount rate used during the first quarter of 2008.

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•

A $12 million increase in Tax equivalent payments reflecting increased gross revenues from the sale of power (excluding sales or deliveries to other federal agencies and off-system sales with other utilities) during 2007 compared to 2006.

The increases in Fuel and purchased power expense, Depreciation, amortization, and accretion expense, Operating and maintenance expense, and Tax equivalent payments were partially offset by a $17 million decrease in Loss on asset impairment. There was no Loss on asset impairment during the first quarter of 2008. During the first quarter of 2007, a $17 million Loss on asset impairment was recorded as a result of a $17 million write-down of a scrubber project at TVA’s Colbert Fossil Plant (“Colbert”). See Note 7.

Other Income. The $15 million decrease in Other income was largely due to decreased interest income from short-term investments and decreased interest earnings on the collateral deposit funds held by TVA. These items were partially offset by a payment received by TVA in connection with a False Claims Act suit.

Unrealized Gain on Derivative Contracts, Net. The $15 million decrease in Unrealized gain on derivative contracts, net was attributable to a change in ratemaking methodology. Beginning in 2008, TVA began using regulatory accounting treatment for swaps and swaptions related to call monetization transactions to better match the income statement recognition of gain and loss with the economic reality of when these transactions actually settle. This treatment removes the non-cash impacts to TVA’s earnings that result from marking the value of these instruments to market each quarter. The values of the swaps and swaptions for the first quarter of 2008 were recorded on TVA’s balance sheet and no income was recognized. However, TVA recognized $15 million as Unrealized gain on derivative contracts, net for the first quarter of 2007.

Interest Expense. Interest expense, outstanding debt, and interest rates for the three months ended December 31, 2007, and 2006, consisted of the following:

Interest Expense For the Three Months Ended December 31

	2007			2006			Percent Change
	As Restated			As Restated
Interest on debt and leaseback obligations	$	341		$	348			(2.0	%)
Amortization of debt discount, issue, and reacquisition costs, net		5			5			0.0	%
Allowance for funds used during construction and nuclear fuel expenditures		(3	)		(49	)		(93.9	%)
Net interest expense	$	343		$	304			12.8	%

	(percent)
	2007			2006			Percent Change
Interest rates (average)
Long-term		5.96			5.94			0.3	%
Discount notes		4.59			5.25			(12.6	%)
Blended		5.87			5.87			0.0	%

Significant items contributing to the $39 million increase in net interest expense included:

•

A $46 million decrease in AFUDC and nuclear fuel expenditures primarily due to a change in ratemaking methodology. TVA continues to capitalize a portion of current interest costs associated with funds invested in most nuclear fuel inventories, but beginning in 2008, interest on funds invested in construction projects will be capitalized only if (1) the expected total cost of a project is $1 billion or more and (2) the estimated construction period is at least three years. Capitalized interest continues to be a component of the asset cost and will be recovered in future periods through depreciation expense. In addition, AFUDC continues to be a reduction to interest expense as costs are incurred. The interest costs associated with funds invested in construction projects that do not satisfy the $1 billion and three-year criteria are no longer capitalized as AFUDC, remain in the Statement of Income, and will be recovered in current year rates as a component of interest expense;

•

An increase in the average long-term interest rate from 5.94 percent during the first quarter of 2007 to 5.96 percent during the same period in 2008; and

•

An increase of $499 million in the average balance of long-term outstanding debt in 2008.

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These items were partially offset by:

•

A decrease in the average discount notes interest rate from 5.25 percent during the first quarter of 2007 to 4.59 percent during the same period in 2008; and

•

A decrease of $852 million in the average balance of discount notes outstanding in 2008.

Off-Balance Sheet Arrangements

TVA has entered into one transaction that could constitute an off-balance sheet arrangement. In February 1997, TVA entered into a purchase power agreement with Choctaw Generation, Inc. (subsequently assigned to Choctaw Generation Limited Partnership) to purchase all the power generated from its facility located in Choctaw County, Mississippi. The facility had a committed capacity of 440 megawatts and the term of the agreement was 30 years. Under the accounting guidance provided by Financial Accounting Standards Board (“FASB”) Interpretation No. 46, “Consolidation of Variable Interest Entities,” as amended by FASB Interpretation No. 46R (as amended, “FIN 46R”), TVA may be deemed to be the primary beneficiary under the contract; however, TVA does not have access to the financial records of Choctaw Generation Limited Partnership. As a result, TVA was unable to determine whether FIN 46R would require TVA to consolidate Choctaw Generation Limited Partnership’s balance sheet, results of operations, and cash flows for the quarter ended December 31, 2007. Power purchases for the first quarter of 2008 under the agreement amounted to $27 million, and the remaining financial commitment under this agreement is $5.2 billion. TVA has no additional financial commitments beyond the purchase power agreement with respect to the facility.

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 generally accepted accounting principles, management 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, changes in financial position, or results of operations. See Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Policies and Estimates in the Annual Report for a discussion of TVA’s critical accounting policies. TVA’s critical accounting policies are also discussed in Note 1 of the Notes to the Annual Report and in Note 1 of the Notes to this Quarterly Report.

TVA’s power rates are not subject to regulation through a public service commission or other similar entity. TVA’s Board is authorized by the TVA Act to set rates for power sold to its customers. This rate-setting authority meets the “self-regulated” provisions of SFAS No. 71, “Accounting for the Effects of Certain Types of Regulation,” and TVA meets the remaining criteria of SFAS No. 71 because (1) TVA’s regulated rates are designed to recover its costs of providing electricity and (2) in view of demand for electricity and the level of competition it is reasonable to assume that the rates, set at levels that will recover TVA’s costs, can be charged and collected. Accordingly, TVA records certain assets and liabilities that result from the regulated ratemaking process that would not be recorded under generally accepted accounting principles for non-regulated entities. Regulatory assets generally represent incurred costs that have been deferred because such costs are likely to be recovered 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. Management assesses whether the regulatory assets are likely to be recovered by considering factors such as applicable regulatory changes, potential legislation, and changes in technology. Based on these assessments, management believes the existing regulatory assets are likely to be recovered. This determination reflects the current regulatory, commercial, and political environment and is subject to change in the future. If future recovery of regulatory assets ceases to be probable, TVA would be required to write-off these costs under the provisions of SFAS No. 101, “Regulated Enterprises–Accounting for the Discontinuation of Application of FASB Statement No. 71.” Any asset write-offs would be required to be recognized in earnings in the period in which future recoveries cease to be probable.

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Changes in Ratemaking

TVA continues to capitalize a portion of current interest costs associated with funds invested in most nuclear fuel inventories, but beginning on October 1, 2007, interest on funds invested in construction projects will be capitalized only if (1) the expected total cost of a project is $1 billion or more and (2) the estimated construction period is at least three years. Capitalized interest continues to be a component of the asset cost and will be recovered in future periods through depreciation expense. In addition, AFUDC continues to be a reduction to interest expense as costs are incurred. The interest cost associated with funds invested in construction projects that do not satisfy the $1 billion and three-year criteria is no longer capitalized as AFUDC, remains in the Statement of Income, and will be recovered in current year rates as a component of interest expense. As a result of the new policy, TVA recorded a total of $3 million in AFUDC in the first quarter of 2008 compared to $49 million for the first quarter of 2007.

The TVA Board approved, beginning in 2008, using regulatory accounting treatment for swaps and swaptions related to call monetization transactions to better match the income statement recognition of gain and loss with the economic reality of when these transactions actually settle. This treatment removes the non-cash impacts to TVA’s earnings that result from marking the value of these instruments to market each quarter. The value of the swaps and swaptions will still be recorded on TVA’s balance sheet, and any interest expense impacts will continue to be reflected in TVA’s income statement. Had TVA not adopted this new accounting treatment, its net loss for the first quarter of 2008 would have decreased by $99 million.

New Accounting Standards and Interpretations

Accounting for Defined Benefit Pension and Other Postretirement Plans. On September 30, 2007, TVA adopted the provisions contained within SFAS No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans - an amendment of FASB Statements No. 87, 88, 106, and 132(R).” This standard requires employers to fully recognize within their financial statements the obligations associated with single-employer defined benefit pension, retiree healthcare, and other postretirement plans. Specifically, the new standard requires an employer to recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year (with limited exceptions); and recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur. Such changes are to be reported within comprehensive income of a business entity (except that regulated entities may report such changes as regulatory assets and/or liabilities in accordance with the provisions of SFAS No. 71), and within changes in net assets of a not-for-profit organization.

Fair Value Measurements. In September 2006, FASB issued SFAS No. 157, “Fair Value Measurements.” This standard provides guidance for using fair value to measure assets and liabilities that currently require fair value measurement. The standard also responds to investors’ requests for expanded information about the extent to which companies measure assets and liabilities at fair value, the information used to measure fair value, and the effect of fair value measurements on earnings. SFAS No. 157 applies whenever other standards require (or permit) assets or liabilities to be measured at fair value but does not expand the use of fair value in any new circumstances. SFAS No. 157 establishes a fair value hierarchy that prioritizes the information used to develop measurement assumptions. The provisions of SFAS No. 157 are effective for financial statements issued for fiscal years beginning after November 15, 2008, and interim periods within those fiscal years. At this time, TVA is evaluating the requirements of this standard and has not yet determined the impact of its implementation, which may or may not be material to TVA’s results of operations or financial position.

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Fair Value Option. In February 2007, FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities — Including an amendment of FASB Statement No. 115.” This standard permits an entity to choose to measure many financial instruments and certain other items at fair value. The fair value option established by SFAS No.159 permits all entities to choose to measure eligible items at fair value at specified election dates. A business entity will report unrealized gains and losses on items for which the fair value option has been elected in earnings at each subsequent reporting date. Most of the provisions in this statement are elective. The provisions of SFAS No. 159 are effective as of the beginning of an entity’s first fiscal year that begins after November 15, 2007. Early adoption is permitted as of the beginning of the previous fiscal year provided that the entity makes that choice in the first 120 days of that fiscal year and also elects to apply the provisions of SFAS No. 157, “Fair Value Measurements.” At this time, TVA is evaluating the requirements of this standard and has not yet determined the potential impact of its implementation, which may or may not be material to TVA’s results of operations or financial position.

Legislative and Regulatory Matters

President’s Budget

On February 4, 2008, the Office of Management and Budget (“OMB”) transmitted the President’s proposed 2009 federal budget to Congress. The proposed budget recommends allowing Congress to establish the amount of TVA’s Office of Inspector General’s budget and directing TVA to fund the amount with power revenues beginning in 2009. Funding for TVA’s Office of the Inspector General is currently established by TVA.

Proposed Legislation

On March 13, 2007, Senators Jim Bunning and Mitch McConnell of Kentucky introduced the Access to Competitive Power Act of 2007 in the Senate. Under this bill, TVA and federal power marketing agencies would be subject to greater FERC jurisdiction with respect to transmission, including rates, terms, and conditions of service. With regard to TVA, the bill would generally provide, among other things, that:

(1)

The anti-cherrypicking provision would not apply with respect to any distributor which provided a termination notice to TVA before December 31, 2006, regardless of whether the notice was later withdrawn or rescinded;

(2)

Distributors that have given termination notices to TVA on or before December 31, 2006, would have express authority under federal law to receive partial requirements from TVA and elect, not later than 180 days after enactment, to rescind the termination notice “without the imposition of a reintegration fee or any similar fee;”

(3)

Distributors that have not given termination notices to TVA on or before December 31, 2006, would have express authority under federal law to receive partial requirements from TVA within a ratable limit, which cumulatively stays within a three percent compounded annual growth rate on the TVA system; and

(4)

Any distributor that terminates its power supply contract with TVA in whole or in part would have the federal statutory right to directly receive its share of SEPA power that is otherwise being delivered to TVA for the benefit of all distributors.

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Environmental Matters

In May 2007, the TVA Board approved a Strategic Plan which addresses the changing business environment and sets a new direction for TVA to remain economically viable and fulfill its stated mission. This Strategic Plan focuses on TVA’s performance in five broad areas and establishes general guidelines for each area. Due to the increasing environmental requirements and expectations coupled with challenges and opportunities related to natural resources, TVA is re-evaluating its high-level environmental policy to align with and execute the direction in the 2007 TVA Strategic Plan. TVA has contracted the services of a consulting firm to assist TVA in updating its environmental policy and developing TVA’s renewable strategy.

As is the case across the utility industry and in other sectors, TVA’s activities are subject to certain federal, state, and local environmental statutes and regulations. Major areas of regulation affecting TVA’s activities include air quality control, water quality control, and management and disposal of solid and hazardous wastes. These activities are described in further detail under Item 1, Business — Environmental Matters and Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations — Environmental Matters in the Annual Report.

The Tennessee Department of Environment and Conservation (“TDEC”) has placed a portion of Barkley Reservoir downstream of TVA's Cumberland Fossil Plant on its draft 2008 list of impaired streams. This list is known as the 303d List after the section in the Clean Water Act that established these requirements. Section 303d of the Clean Water Act requires states to develop and report to the EPA on a two-year cycle a list of waters that are "water quality limited" or are expected to not meet water quality standards in the next two years and need additional pollution controls. This section of Barkley Reservoir had not been listed previously. The reservoir conditions in 2007, especially for temperature and dissolved oxygen, changed significantly due primarily to reduced flows in the Cumberland River resulting from emergency dam repairs on the U. S. Army Corps of Engineers' (“Corps”) Wolf Creek and Center Hill dams coupled with the most severe drought on record in the region. The prospect of continued reduced flows through the Cumberland River system during the period required to complete the necessary repairs to Wolf Creek and Center Hill dams may impact the generation of electricity from TVA's Cumberland and Gallatin fossil plants. TVA is working with the Corps and TDEC to minimize the impacts to TVA's generating plants and improve the conditions observed in the river in 2007.

Legal

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Case Involving Alleged Modifications to the Colbert Fossil Plant. The National Parks Conservation Association, Inc. (“NPCA”), and Sierra Club, Inc. (“Sierra Club”), filed suit on February 13, 2001, in the United States District Court for the Northern District of Alabama, alleging that TVA violated the Clean Air Act (“CAA”) and implementing regulations at TVA’s Colbert Fossil Plant (“Colbert”), a coal-fired electric generating facility located in Tuscumbia, Alabama. The plaintiffs allege that TVA made major modifications to Colbert Unit 5 without obtaining preconstruction permits (in alleged violation of the Prevention of Significant Deterioration (“PSD”) program and the Nonattainment New Source Review (“NNSR”) program) and without complying with emission standards (in alleged violation of the New Source Performance Standards (“NSPS”) program). The plaintiffs seek injunctive relief; civil penalties of $25,000 per day for each violation on or before January 30, 1997, and $27,500 per day for each violation after that date; an order that TVA pay up to $100,000 for beneficial mitigation projects; and costs of litigation, including attorney and expert witness fees. On November 29, 2005, the district court held that sovereign immunity precluded the plaintiffs from recovering civil penalties against TVA. On January 17, 2006, the district court dismissed the action, on the basis that the plaintiffs failed to provide adequate notice of NSPS claims and that the statute of limitations curtailed the PSD and NNSR claims. The plaintiffs appealed to the United States Court of Appeals for the Eleventh Circuit (“Eleventh Circuit”) on January 25, 2006. In an October 4, 2007 decision, the Eleventh Circuit affirmed dismissal of the lawsuit. In January 2008, the plaintiffs filed a petition for a writ of certiorari, asking the United States Supreme Court to hear an appeal of the Eleventh Circuit’s decision.

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Notification of Potential Liability for Ward Transformer Site. EPA and a working group of potentially responsible parties (“PRPs”) have provided documentation showing that TVA sent electrical equipment containing polychlorinated biphenyls (“PCBs”) to the Ward Transformer site in Raleigh, North Carolina. Under the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), any entity which arranges for disposal of a CERCLA hazardous substance at a site may bear liability for the cost of cleaning up the site. The working group is cleaning up on-site contamination in accordance with an agreement with EPA and plans to sue non-participating PRPs for contribution. The estimated cost of the cleanup is $20 million. In addition, EPA likely has incurred several million dollars in response costs, and the working group has reimbursed EPA approximately $725,000 of those costs. EPA has also proposed a cleanup plan for off-site contamination. The present worth cost estimate for performing the proposed plan is about $5 million. In addition, there may be natural resource damages liability related to this site, but TVA is not aware of any estimated amount for any such damages.

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Management Changes

TVA Board Nominations

On December 31, 2007, Congress adjourned without the Senate having voted upon President George W. Bush’s nominations of Susan Richardson Williams, Thomas C. Gilliland, and Bishop William Graves to the TVA Board. Because Congress adjourned and their nominations were not approved, Ms. Williams and Bishop Graves are no longer directors of TVA. As a result of these vacancies and a previous vacancy which Mr. Gilliland had been nominated to fill, there are currently six directors on the Board. Under the TVA Act, while the TVA Board may have up to nine directors, a quorum for transacting business is five directors.

New Vice President and Controller Named

On December 4, 2007, TVA announced the appointment of John M. Thomas III as Vice President and Controller and its Chief Accounting Officer, effective January 7, 2008. He succeeded Randall P. Trusley, who retired from TVA effective January 4, 2008.

Mr. Thomas is responsible for the development and maintenance of TVA accounting policies and practices, compliance with SEC reporting requirements including disclosures, internal controls, and financial reports, development of policy and methods for business planning, budgeting and financial management, and ensuring consistency with TVA financial policy. In addition, he provides oversight and analysis of financial and performance reporting and serves as the primary management point of contact for the Audit and Ethics Committee.

Executive Vice President, Power System Operations Retirement

W. Terry Boston, TVA’s Executive Vice President, Power System Operations, retired from TVA on February 1, 2008. Mr. Boston had worked at TVA for almost 36 years. He left TVA to become the president and chief executive officer of PJM Interconnection, which operates a large centrally dispatched electric grid in the eastern United States.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There are no material changes related to market risk from the 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.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

A re-evaluation has been performed under the supervision of TVA management (including the president and chief executive officer) and members of the disclosure control committee (including the chief financial officer and the vice president and controller) of the effectiveness of TVA’s disclosure controls and procedures as of December 31, 2007. Based on that re-evaluation, the president and chief executive officer and members of the disclosure control committee (including the chief financial officer and the vice president and controller) concluded that, based on the material weakness described below, TVA’s disclosure controls and procedures were not effective as of December 31, 2007 to ensure that information required to be disclosed in reports TVA files or submits under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized, and reported within the time periods specified in Securities and Exchange Commission rules and forms. This includes controls and procedures designed to ensure that such information is accumulated and communicated to TVA management, including the president and chief executive officer, the disclosure control committee, and the chief financial officer, as appropriate, to allow timely decisions regarding required disclosure. This conclusion is different than the conclusion disclosed in the original filing of TVA’s Quarterly Report on Form 10-Q for the quarter ended December 31, 2007.

Subsequent to the periods covered by this report, TVA management identified a material weakness in internal controls related to TVA’s unbilled revenue calculation. The estimation process implemented in September 2006 utilized the distributors’ average rates and an estimate of the number of days of revenue outstanding to reflect the delay in reporting the end-use sales to TVA (“days outstanding”). The number of days outstanding was derived using a procedure similar to a cross-correlation calculation that compared the monthly retail load to the monthly wholesale load. The intent was to reflect in the unbilled estimate the end-use sales that would be reported that month by distributors plus any remaining sales that would not be reported until the following month due to the delay between wholesale delivery and end-use reporting.

TVA has used a new process for estimating unbilled revenue for periods presented in this Form 10-Q/A. This process carries over only the portion of sales from the distributor’s meter read date to the month-end. Those sales, along with the current month sales, are then priced at rates based on each distributor’s customer and product mix. Additionally, the true-up component has been added to the unbilled calculation to reflect any timing differences that occur between the retail and wholesale billing cycles.

TVA management believes that a control system, no matter how well designed and operated, cannot provide absolute assurance that the objectives of the control system are met, and no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within a company can be detected.

TVA’s controls and procedures are designed to provide reasonable, but not absolute, assurance that the objectives will be met. It should be noted that the design of any system of controls is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions, regardless of how remote.

Changes in Internal Control over Financial Reporting

During the most recent fiscal quarter, there were no changes in TVA’s internal control over financial reporting that materially affected, or are reasonably likely to materially affect, TVA’s internal control over financial reporting.

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PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

See Note 8 in this Quarterly Report for a discussion of legal proceedings affecting TVA.

ITEM 1A. RISK FACTORS

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

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

None.

ITEM 5. OTHER INFORMATION

In accordance with the Board’s September 27, 2007 approval of its Audit and Ethics Committee’s recommendation, Ernst & Young LLP became TVA’s independent registered public accounting firm beginning December 12, 2007.

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ITEM 6. EXHIBITS

Exhibit No.		Description

3.1		Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee *

10.1		TVA Discount Notes Selling Group Agreement *

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

* Previously filed

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SIGNATURES

Pursuant to the requirements 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: December 11, 2008

	TENNESSEE VALLEY AUTHORITY
	(Registrant)

By:	/s/ Tom D. Kilgore
	Tom D. Kilgore
	President and Chief Executive Officer
	(Principal Executive Officer)



By:	/s/ Kimberly S. Greene
	Kimberly S. Greene
	Chief Financial Officer and Executive
	Vice President, Financial Services
	(Principal Financial Officer)

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EXHIBIT INDEX

Exhibit No.		Description

3.1		Tennessee Valley Authority Act of 1933, as amended, 16 U.S.C. §§ 831-831ee *

10.1		TVA Discount Notes Selling Group Agreement *

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

* Previously filed

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