Tennessee Valley Authority - Quarter Report: 2007 June (Form 10-Q)
Table of Contents
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark
One)
þ | QUARTERLY REPORT PURSUANT TO SECTION 13, 15(d), OR 37 OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended June 30, 2007
OR
o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from to
Commission file number 000-52313
TENNESSEE VALLEY AUTHORITY
(Exact name of registrant as specified in its charter)
A corporate agency of the United States created by an act of Congress (State or other jurisdiction of incorporation or organization) |
62-0474417 (I.R.S. Employer Identification No.) |
|
400 W. Summit Hill Drive Knoxville, Tennessee (Address of principal executive offices) |
37902 (Zip Code) |
(865) 632-2101
(Registrants telephone number, including area code)
(Registrants telephone number, including area code)
None
(Former name, former address and former fiscal year, if changed since last report)
(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 or 15(d) 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 þ No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer,
or a non-accelerated filer. See definition of accelerated filer and large accelerated filer in
Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer o Accelerated filer o Non-accelerated filer þ
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the
Exchange Act). Yes o No þ
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Ex-10.1 Amendment to Credit Facility | ||||||||
Ex-31.1 Section 302 Certification of the CEO | ||||||||
Ex-31.2 Section 302 Certification of the CFO | ||||||||
Ex-32.1 Section 906 Certification of the CEO | ||||||||
Ex-32.2 Section 906 Certification of the CFO |
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FORWARD-LOOKING INFORMATION
This Quarterly Report on Form 10-Q (this Quarterly Report) contains forward-looking
statements relating to future events and future performance. All statements other than those that
are purely historical may be forward-looking statements.
In certain cases, forward-looking statements can be identified by the use of words such as
may, will, should, expect, anticipate, believe, intend, project, plan, predict,
assume, forecast, estimate, objective, possible, probably, likely, potential, 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 Tennessee Valley Authoritys (TVA) pension plans and nuclear decommissioning trust; | ||
| The impact of new accounting pronouncements and interpretations, including Statement of Financial Accounting Standards No. 158, Employers Accounting for Defined Benefit Pension and Other Postretirement Plans an amendment of FASB Statements No. 87, 88, 106, and 132(R); | ||
| Estimates of amounts to be reclassified from Other Comprehensive Income to earnings over the next year; | ||
| TVAs plans to continue using short-term debt to meet current obligations; and | ||
| The anticipated cost and timetable for returning Watts Bar Nuclear Plant Unit 2 to service. |
Although 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: |
| TVAs protected service area, | ||
| The sole authority of the TVA Board of Directors to set power rates, | ||
| Various environmental and nuclear matters, | ||
| TVAs management of the Tennessee River system, | ||
| TVAs credit rating, and | ||
| TVAs debt ceiling; |
| Performance of TVAs generation and transmission assets; | ||
| Availability of fuel supplies; | ||
| Purchased power price volatility; | ||
| Reliability of purchased power providers, fuel suppliers, and other counterparties; | ||
| 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; | ||
| Failure of transmission facilities; | ||
| An accident at any nuclear facility, even one unaffiliated with TVA; | ||
| Catastrophic events such as fires, earthquakes, floods, pandemics, wars, terrorist activities, and other similar events, especially if these events occur in or near TVAs service area; | ||
| Events at facilities not owned by TVA that affect the supply of water to TVAs generation facilities; | ||
| 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 or its counterparties; | ||
| Rising pension costs and health care expenses; |
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| Increases in TVAs financial liability for decommissioning its nuclear facilities; | ||
| Limitations on TVAs ability to borrow money; | ||
| Changes in economic conditions; | ||
| Ineffectiveness of TVAs disclosure controls and procedures and internal control over financial reporting; | ||
| Changes in accounting standards; | ||
| The loss of TVAs ability to use regulatory accounting; | ||
| Loss of key personnel; | ||
| Changes in technology; | ||
| Changes in the market for TVA securities; and | ||
| Unforeseeable events. |
Additionally, other risks that may cause actual results to differ from forward-looking
statements are set forth in TVAs Annual Report on Form 10-K/A for the fiscal year ended September
30, 2006, particularly in Item 1A, Risk Factors, and in this Quarterly Report. New factors emerge
from time to time, and it is not possible for management to predict all such factors or to assess
the extent to which any factor or combination of factors may impact TVAs 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 (2007, 2006, etc.) in this Quarterly Report refer to TVAs
fiscal years ending September 30.
Notes
References to Notes are to the Notes to Financial Statements contained in Part 1, Item 1,
Financial Statements in this Quarterly Report.
Available Information
The public may read and copy any reports or other information that TVA files with the
Securities and Exchange Commission (SEC) at the SECs 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. TVAs SEC reports are also available to the
public without charge from the website maintained by the SEC at www.sec.gov and TVAs website at
www.tva.com/finance. Information contained on TVAs website shall not be deemed to be incorporated
into, or to be a part of, this Quarterly Report.
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PART
I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
TENNESSEE VALLEY AUTHORITY
STATEMENTS OF INCOME (UNAUDITED)
(in millions)
(in millions)
Three months ended | Nine months ended | |||||||||||||||
June 30 | June 30 | |||||||||||||||
2007 | 2006 | 2007 | 2006 | |||||||||||||
Operating revenues |
||||||||||||||||
Sales of electricity
|
||||||||||||||||
Municipalities and cooperatives |
$ | 1,863 | $ | 1,898 | $ | 5,527 | $ | 5,406 | ||||||||
Industries directly served |
304 | 275 | 907 | 750 | ||||||||||||
Federal agencies and other |
29 | 27 | 80 | 85 | ||||||||||||
Other revenue |
40 | 42 | 106 | 106 | ||||||||||||
Total operating revenues |
2,236 | 2,242 | 6,620 | 6,347 | ||||||||||||
Operating expenses |
||||||||||||||||
Fuel and purchased power |
779 | 833 | 2,342 | 2,295 | ||||||||||||
Operating and maintenance |
621 | 585 | 1,782 | 1,752 | ||||||||||||
Depreciation, amortization, and accretion |
366 | 363 | 1,104 | 1,140 | ||||||||||||
Tax equivalents |
110 | 93 | 327 | 280 | ||||||||||||
Total operating expenses |
1,876 | 1,874 | 5,555 | 5,467 | ||||||||||||
Operating income |
360 | 368 | 1,065 | 880 | ||||||||||||
Other income |
30 | 25 | 57 | 48 | ||||||||||||
Other expense |
(1 | ) | (1 | ) | (1 | ) | (1 | ) | ||||||||
Unrealized gain on derivative contracts, net |
98 | 75 | 129 | 110 | ||||||||||||
Interest expense |
||||||||||||||||
Interest on debt |
334 | 342 | 1,009 | 1,016 | ||||||||||||
Amortization of debt discount, issue, and reacquisition costs, net |
4 | 5 | 14 | 15 | ||||||||||||
Allowance for funds used during construction and nuclear fuel expenditures |
(45 | ) | (42 | ) | (144 | ) | (117 | ) | ||||||||
Net interest expense |
293 | 305 | 879 | 914 | ||||||||||||
Net income |
$ | 194 | $ | 162 | $ | 371 | $ | 123 | ||||||||
The accompanying Notes are an integral part of these financial statements.
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TENNESSEE VALLEY AUTHORITY
BALANCE SHEETS (UNAUDITED)
(in millions)
(in millions)
At June 30 | At September 30 | |||||||
2007 | 2006 | |||||||
ASSETS |
||||||||
Current assets |
||||||||
Cash and cash equivalents |
$ | 137 | $ | 536 | ||||
Restricted cash and investments (Note 1) |
184 | 198 | ||||||
Accounts receivable, net |
1,258 | 1,359 | ||||||
Inventories and other |
719 | 576 | ||||||
Total current assets |
2,298 | 2,669 | ||||||
Property, plant, and equipment |
||||||||
Completed plant |
36,768 | 35,652 | ||||||
Less accumulated depreciation |
(15,980 | ) | (15,331 | ) | ||||
Net completed plant |
20,788 | 20,321 | ||||||
Construction in progress |
3,369 | 3,539 | ||||||
Nuclear fuel and capital leases |
601 | 574 | ||||||
Total property, plant, and equipment, net |
24,758 | 24,434 | ||||||
Investment funds |
1,106 | 972 | ||||||
Regulatory and other long-term assets (Note 1) |
||||||||
Deferred nuclear generating units |
3,227 | 3,521 | ||||||
Other regulatory assets |
1,839 | 1,809 | ||||||
Subtotal |
5,066 | 5,330 | ||||||
Other long-term assets |
619 | 1,115 | ||||||
Total deferred charges and other assets |
5,685 | 6,445 | ||||||
Total assets |
$ | 33,847 | $ | 34,520 | ||||
LIABILITIES AND PROPRIETARY CAPITAL |
||||||||
Current liabilities |
||||||||
Accounts payable |
$ | 766 | $ | 890 | ||||
Accrued liabilities |
195 | 211 | ||||||
Collateral funds held |
183 | 195 | ||||||
Accrued interest |
262 | 403 | ||||||
Current portion of lease/leaseback obligations |
43 | 37 | ||||||
Current portion of energy prepayment obligations |
106 | 106 | ||||||
Short-term debt, net |
2,610 | 2,376 | ||||||
Current maturities of long-term debt (Note 3) |
90 | 985 | ||||||
Total current liabilities |
4,255 | 5,203 | ||||||
Other liabilities |
||||||||
Other liabilities |
2,190 | 2,305 | ||||||
Regulatory liabilities (Note 1) |
109 | 575 | ||||||
Asset retirement obligations |
2,142 | 1,985 | ||||||
Lease/leaseback obligations |
1,031 | 1,071 | ||||||
Energy prepayment obligations (Note 1) |
1,059 | 1,138 | ||||||
Total other liabilities |
6,531 | 7,074 | ||||||
Long-term debt, net (Note 3) |
20,083 | 19,544 | ||||||
Total liabilities |
30,869 | 31,821 | ||||||
Commitments and contingencies |
||||||||
Proprietary capital |
||||||||
Appropriation investment |
4,748 | 4,763 | ||||||
Retained earnings |
1,929 | 1,565 | ||||||
Accumulated other comprehensive income |
(19 | ) | 43 | |||||
Accumulated net expense of stewardship programs |
(3,680 | ) | (3,672 | ) | ||||
Total proprietary capital |
2,978 | 2,699 | ||||||
Total liabilities and proprietary capital |
$ | 33,847 | $ | 34,520 | ||||
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 nine months ended June 30
(in millions)
For the nine months ended June 30
(in millions)
2007 | 2006 | |||||||
Cash flows from operating activities |
||||||||
Net income |
$ | 371 | $ | 123 | ||||
Adjustments to reconcile net income to net cash provided by operating activities
|
||||||||
Depreciation, amortization, and accretion |
1,134 | 1,156 | ||||||
Nuclear refueling outage amortization |
62 | 66 | ||||||
Loss on project write-downs |
23 | | ||||||
Amortization of nuclear fuel |
94 | 96 | ||||||
Non-cash retirement benefit expense |
151 | 226 | ||||||
Net unrealized gain on derivative contracts |
(129 | ) | (110 | ) | ||||
Prepayment credits applied to revenue |
(79 | ) | (79 | ) | ||||
Fuel cost adjustment deferral |
(126 | ) | | |||||
Other, net |
13 | 14 | ||||||
Changes in current assets and liabilities
|
||||||||
Accounts receivable, net |
122 | 48 | ||||||
Inventories and other |
(162 | ) | (168 | ) | ||||
Accounts payable and accrued liabilities |
(119 | ) | 20 | |||||
Accrued interest |
(140 | ) | (83 | ) | ||||
Refueling outage costs |
(90 | ) | (59 | ) | ||||
Pension contributions |
(56 | ) | (56 | ) | ||||
Other, net |
43 | 24 | ||||||
Net cash provided by operating activities |
1,112 | 1,218 | ||||||
Cash flows from investing activities |
||||||||
Construction expenditures |
(1,041 | ) | (947 | ) | ||||
Combustion turbine asset acquisitions |
(100 | ) | | |||||
Nuclear fuel expenditures |
(130 | ) | (216 | ) | ||||
Change in restricted cash and investments |
14 | (71 | ) | |||||
Proceeds (purchases) of investments |
2 | (4 | ) | |||||
Loans and other receivables
|
||||||||
Advances |
(7 | ) | (11 | ) | ||||
Repayments |
13 | 10 | ||||||
Proceeds from sale of receivables/loans |
2 | 7 | ||||||
Other, net |
1 | (1 | ) | |||||
Net cash used in investing activities |
(1,246 | ) | (1,233 | ) | ||||
Cash flows from financing activities |
||||||||
Long-term debt |
||||||||
Issues |
36 | 1,105 | ||||||
Redemptions and repurchases |
(469 | ) | (159 | ) | ||||
Short-term issues, net |
234 | (894 | ) | |||||
Payments on combustion turbine financing |
(27 | ) | (26 | ) | ||||
Payments on equipment financing |
(7 | ) | (6 | ) | ||||
Payments from other financing |
(1 | ) | | |||||
Financing costs, net |
(1 | ) | (13 | ) | ||||
Payments to U.S. Treasury |
(30 | ) | (29 | ) | ||||
Net cash used in financing activities |
(265 | ) | (22 | ) | ||||
Net change in cash and cash equivalents |
(399 | ) | (37 | ) | ||||
Cash and cash equivalents at beginning of period |
536 | 538 | ||||||
Cash and cash equivalents at end of period |
$ | 137 | $ | 501 | ||||
The accompanying Notes are an integral part of these financial statements.
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TENNESSEE VALLEY AUTHORITY
STATEMENTS OF CHANGES IN PROPRIETARY CAPITAL (UNAUDITED)
(in millions)
(in millions)
For the three months ended June 30, 2007 and 2006
Accumulated | Accumulated | |||||||||||||||||||||||
Other | Net Expense | |||||||||||||||||||||||
Appropriation | Retained | Comprehensive | of Stewardship | Comprehensive | ||||||||||||||||||||
Investment | Earnings | Income (Loss) | Programs | Total | Income (Loss) | |||||||||||||||||||
Balance at March 31, 2006 |
$ | 4,773 | $ | 1,202 | $ | 116 | $ | (3,667 | ) | $ | 2,424 | $ | | |||||||||||
Net income (loss) |
| 164 | | (2 | ) | 162 | 162 | |||||||||||||||||
Return on appropriation investment |
| (6 | ) | | | (6 | ) | | ||||||||||||||||
Other comprehensive loss (Note 2) |
| | (4 | ) | | (4 | ) | (4 | ) | |||||||||||||||
Return of appropriation investment |
(5 | ) | | | | (5 | ) | | ||||||||||||||||
Balance at June 30, 2006 |
$ | 4,768 | $ | 1,360 | $ | 112 | $ | (3,669 | ) | $ | 2,571 | $ | 158 | |||||||||||
Balance at March 31, 2007 |
$ | 4,753 | $ | 1,736 | $ | 6 | $ | (3,676 | ) | $ | 2,819 | $ | | |||||||||||
Net income (loss) |
| 198 | | (4 | ) | 194 | 194 | |||||||||||||||||
Return on appropriation investment |
| (5 | ) | | | (5 | ) | | ||||||||||||||||
Other comprehensive loss (Note 2) |
| | (25 | ) | | (25 | ) | (25 | ) | |||||||||||||||
Return of appropriation investment |
(5 | ) | | | | (5 | ) | | ||||||||||||||||
Balance at June 30, 2007 |
$ | 4,748 | $ | 1,929 | $ | (19 | ) | $ | (3,680 | ) | $ | 2,978 | $ | 169 | ||||||||||
For the nine months ended June 30, 2007 and 2006
Accumulated | Accumulated | |||||||||||||||||||||||
Other | Net Expense | |||||||||||||||||||||||
Appropriation | Retained | Comprehensive | of Stewardship | Comprehensive | ||||||||||||||||||||
Investment | Earnings | Income (Loss) | Programs | Total | Income (Loss) | |||||||||||||||||||
Balance at September 30, 2005 |
$ | 4,783 | $ | 1,244 | $ | 27 | $ | (3,662 | ) | $ | 2,392 | $ | | |||||||||||
Net income (loss) |
| 130 | | (7 | ) | 123 | 123 | |||||||||||||||||
Return on appropriation investment |
| (14 | ) | | | (14 | ) | | ||||||||||||||||
Other comprehensive income (Note 2) |
| | 85 | | 85 | 85 | ||||||||||||||||||
Return of appropriation investment |
(15 | ) | | | | (15 | ) | | ||||||||||||||||
Balance at June 30, 2006 |
$ | 4,768 | $ | 1,360 | $ | 112 | $ | (3,669 | ) | $ | 2,571 | $ | 208 | |||||||||||
Balance at September 30, 2006 |
$ | 4,763 | $ | 1,565 | $ | 43 | $ | (3,672 | ) | $ | 2,699 | $ | | |||||||||||
Net income (loss) |
| 379 | | (8 | ) | 371 | 371 | |||||||||||||||||
Return on appropriation investment |
| (15 | ) | | | (15 | ) | | ||||||||||||||||
Other comprehensive loss (Note 2) |
| | (62 | ) | | (62 | ) | (62 | ) | |||||||||||||||
Return of appropriation investment |
(15 | ) | | | | (15 | ) | | ||||||||||||||||
Balance at June 30, 2007 |
$ | 4,748 | $ | 1,929 | $ | (19 | ) | $ | (3,680 | ) | $ | 2,978 | $ | 309 | ||||||||||
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)
(Dollars in millions except where noted)
1. Summary of Significant Accounting Policies
Organization
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 (2000 & Supp. IV 2004) (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,
industry, and other stewardship purposes.
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 portions of northern Georgia, western North Carolina, and southwestern Virginia to a population
of approximately 8.7 million people. The power program has historically been separate and distinct
from the stewardship programs. It is required to be self-supporting from power revenues and
proceeds from power financings, such as proceeds from the issuance of bonds, notes, and other
evidences of indebtedness. Although TVA does not currently receive congressional appropriations,
it is required to make payments to the U.S. Treasury in repayment of and as a return on the
appropriation investment the United States provided TVA for its power program. Until 2000, most of
the funding for TVAs stewardship programs was provided by congressional appropriations. These
programs are now funded largely with power revenues. Certain stewardship activities are also funded
with various revenues and user fees. TVAs stewardship activities 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, TVAs
stewardship assets and properties are included as part of the power program, TVAs only operating
segment.
Power rates are established by the TVA Board of Directors (the 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; tax
equivalent payments to states and counties; debt service on outstanding indebtedness; payments to
the U.S. Treasury in repayment of and as a return on the outstanding amount TVA is required to
repay the United States for its investment in TVAs power facilities; and such additional margin as
the TVA Board may consider desirable for investment in power system assets, retirement of
outstanding indebtedness in advance of maturity, additional reduction of the outstanding amount TVA
is required to repay the United States for its investment in TVAs power facilities, and other
purposes connected with TVAs power business. In setting rates, the TVA Board is charged by the TVA
Act to have due regard for the primary objectives of the TVA Act, including the objective that
power shall be sold at rates as low as are feasible. Rates set by the TVA Board are not subject to
review or approval by any state or 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 of America for interim financial information.
Accordingly, TVAs 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, 2006, and the notes thereto, which are contained in TVAs Annual
Report on Form 10-K/A for the fiscal year ended September 30, 2006 (the Annual Report).
Subsequent to its fourth quarter of 2006 closing, TVA reviewed projects related to
construction work in progress and identified errors in classification related primarily to 2006 and
prior periods. Based on the results of the review, TVA recorded project write-downs of $5 million
in the first quarter of 2007. Additionally, TVA recorded a $4 million expense during the first
quarter of 2007 related to litigation pending during the fourth quarter of 2006. These charges are
included in Operating and Maintenance expense on the Statement of Income for the nine
months ended June 30, 2007. TVA uses cash flows from operating activities as its primary measure
of materiality. As such, TVA determined that these noncash adjustments were not material to its
reported results for prior and current periods on a quantitative basis, based on TVAs operating
cash flows, or on a qualitative basis, and did not require restatement of those results.
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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 TVAs financial position and results of operations for the
interim periods. Due to seasonal weather variations, the timing of planned maintenance and
refueling outages of electric generating units, and other factors, the results of operations for
interim periods are not necessarily indicative of amounts expected for the entire year.
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
TVAs fiscal year ends September 30. Unless otherwise indicated, years (2007, 2006, etc.)
refer to TVAs fiscal years.
Reclassifications
Certain reclassifications have been made to the 2006 financial statements to conform to the
2007 presentation, including the reclassification of interest income of approximately $6 million
and $17 million for the three and nine months ended June 30, 2006, respectively, which was
previously included in Interest on Debt on the Statement of Income. Interest income is now
included in Other Income.
Beginning with October 2006, certain items previously considered revenue from Sales of
Electricity were reclassified as Other Revenue. These items are not directly
associated with the sale of electricity and include delivery point charges, administrative charges,
and customer charges. Previously reported sales of electricity of approximately $5 million and
$17 million for the three and nine months ended June 30, 2006, respectively, are now included in
Other Revenue. Additionally, certain items previously considered revenue from Other
Revenue were reclassified as Other Income. These items were not directly associated
with revenue derived from electric operations but were associated with the operation of service
organizations which provide maintenance and testing services. Previously reported revenue from
these items of approximately $8 million and $3 million for the three and nine months ended June 30,
2006, respectively, are now included in Other Income.
These reclassifications had no effect on previously reported results of operations and net
cash flows.
Revision to Statement of Cash Flows
As of September 30, 2006, TVA began reporting the allowance for funds used during construction
(AFUDC) related to construction expenditures and nuclear fuel expenditures as a noncash component
of investing activities rather than a noncash component of operating activities. The revised
classification is consistent with guidance for the cash flow presentation for capitalized interest.
The previous method of reporting AFUDC was consistent with the industry practice for the combined
reporting of debt and equity AFUDC. The result of this reclassification is an increase in cash from
operating activities of $117 million and an increase in funds used by investing activities of $117
million for the nine months ended June 30, 2006.
Restricted Cash and Investments
As of June 30, 2007, and September 30, 2006, TVA had $184 million and $198 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, which result in the funds being reported in Restricted Cash and
Investments. The corresponding liability is included in Collateral Funds Held on the
June 30, 2007, and September 30, 2006 Balance Sheets.
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Accounts Receivables
Accounts receivable primarily consist of amounts due from power sales. The table below
summarizes the types and amounts of receivables.
Accounts Receivable
At June 30 | At September 30 | |||||||
2007 | 2006 | |||||||
Power receivables billed |
$ | 197 | $ | 303 | ||||
Power receivables unbilled |
1,041 | 1,031 | ||||||
Total power receivables |
1,238 | 1,334 | ||||||
Other receivables |
23 | 35 | ||||||
Allowance for uncollectible accounts |
(3 | ) | (10 | ) | ||||
Net accounts receivable |
$ | 1,258 | $ | 1,359 | ||||
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 Deferred Nuclear Generating Units and
Other Regulatory Assets on the June 30, 2007, and September 30, 2006 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,
unrealized losses related to power purchase contracts, deferred capital lease asset costs, a
deferred loss relating to TVAs financial trading program, minimum pension liability, and,
beginning in 2007, an estimated fuel cost adjustment (FCA) related to rate actions taken during
2006. All regulatory assets are probable of recovery in future revenues. Components of
Regulatory Liabilities include unrealized gains on coal purchase contracts and capital
lease liabilities.
TVAs regulatory assets and liabilities are summarized in the table below.
TVA Regulatory Assets and Liabilities
At June 30 | At September 30 | |||||||
2007 | 2006 | |||||||
Regulatory Assets |
||||||||
Minimum pension liability |
$ | 914 | $ | 914 | ||||
Nuclear decommissioning costs |
394 | 474 | ||||||
Debt reacquisition costs |
216 | 232 | ||||||
Deferred trading program loss |
22 | 6 | ||||||
Deferred outage costs |
113 | 85 | ||||||
Deferred capital lease asset costs |
69 | 76 | ||||||
Unrealized losses on purchased power contracts |
1 | 22 | ||||||
Fuel cost adjustment |
110 | | ||||||
Subtotal |
1,839 | 1,809 | ||||||
Deferred nuclear generating units |
3,227 | 3,521 | ||||||
Total |
$ | 5,066 | $ | 5,330 | ||||
Regulatory Liabilities |
||||||||
Unrealized gain on coal purchase contracts |
$ | 36 | $ | 487 | ||||
Capital lease liability |
73 | 88 | ||||||
Total |
$ | 109 | $ | 575 | ||||
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TVA has 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 June 30, 2007 Balance Sheet. See
Reserve for Future Generation in this Note 1.
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 third quarter of 2007, TVAs total asset retirement obligations (ARO) liability
increased $30 million. The increase was comprised of $7 million in new AROs plus $23 million in
ARO expense (accretion of the liability). Correspondingly for the third quarter of 2006, the ARO
liability decreased $129 million. The decrease was comprised of a reduction in estimates to future
cash flows of $153 million offset by a $24 million increase in ARO expense.
During the first nine months of 2007, TVAs total ARO liability increased $157 million. The
increase was comprised of $90 million in new AROs plus $67 million in ARO expense (accretion of the
liability). Correspondingly, for the first nine months of 2006, the ARO liability decreased $165
million. The decrease was comprised of a reduction in estimates to future cash flows of $242
million offset by a $77 million increase in ARO expense.
Reconciliation of Asset Retirement Obligations Liability
Three Months Ended | Nine Months Ended | |||||||||||||||
June 30 | June 30 | |||||||||||||||
2007 | 2006 | 2007 | 2006 | |||||||||||||
Balance at beginning of period |
$ | 2,112 | $ | 1,821 | $ | 1,985 | $ | 1,857 | ||||||||
Changes in nuclear estimates to future cash flows |
7 | (153 | ) | 89 | (242 | ) | ||||||||||
Non-nuclear additional obligations |
| | 1 | | ||||||||||||
7 | (153 | ) | 90 | (242 | ) | |||||||||||
Add: ARO (accretion) expense |
||||||||||||||||
Nuclear accretion (recorded as a regulatory asset) |
16 | 21 | 46 | 67 | ||||||||||||
Non-nuclear accretion (charged to expense) |
7 | 3 | 21 | 10 | ||||||||||||
23 | 24 | 67 | 77 | |||||||||||||
Balance at end of period |
$ | 2,142 | $ | 1,692 | $ | 2,142 | $ | 1,692 | ||||||||
TVA periodically reviews the estimated costs of decommissioning its nuclear plants. Based
on a cost study, TVA reduced the liability $89 million in 2006.
The increase in the nuclear liability in 2007 is comprised of a second quarter increase of $82
million based on a 2007 cost study, which accounted for biennial changes in labor rates, and a
third quarter increase of $7 million due to the replacement of steam generators at Watts Bar
Nuclear Plant.
Energy Prepayment Obligations
As of June 30, 2007, TVA had entered into sales agreements for 54.5 discounted energy units
totaling $54.5 million. Total credits applied to power billings on a cumulative basis during the
life of the program through June 30, 2007, exceeded $24.4 million. Of this amount, over $1 million
was recognized as revenue for each of the quarterly periods ended June 30, 2007, and 2006.
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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 MLGWs 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
June 30, 2007, exceeded $365 million. Of this amount, $25 million was recognized as revenue for
each of the quarterly periods ended June 30, 2007, and 2006. These amounts were based on the ratio
of kilowatt-hours of electricity delivered to the total kilowatt-hours under contract.
At June 30, 2007, and September 30, 2006, obligations for these energy prepayments were $1,165
million and $1,244 million, respectively. These amounts are included in Energy Prepayment
Obligations and Current Portion of Energy Prepayment Obligations on the June 30,
2007, and September 30, 2006 Balance Sheets.
Impact of New Accounting Pronouncements and Interpretations
Accounting Changes and Error Corrections. In May 2005, the Financial Accounting
Standards Board (FASB) issued SFAS No. 154, Accounting Changes and Error Corrections a
replacement of APB Opinion No. 20 and FASB Statement No. 3, which replaces Accounting Principles
Board (APB) Opinion No. 20, Accounting Changes, and SFAS No. 3, Reporting Accounting Changes
in Interim Financial Statements. This statement applies to all voluntary changes in accounting
principles and also applies to changes required by an accounting pronouncement in the unusual
instance that the pronouncement does not include specific transition provisions. This statement
requires, unless impracticable, retrospective application to prior periods financial statements of
changes in accounting principles. If it is impracticable to determine the period-specific effects
of an accounting change on one or more individual prior periods presented, this statement requires
that the new accounting principle be applied to the balances of assets and liabilities as of the
beginning of the earliest period for which retrospective application is practicable and that a
corresponding adjustment be made to the opening balance of retained earnings for that period rather
than being reported in an income statement. When it is impracticable to determine the cumulative
effect of applying a change in accounting principle to all prior periods, this statement requires
that the new accounting principle be applied as if it were adopted prospectively from the earliest
date practicable. This statement also requires that a change in depreciation, amortization, or
depletion method for long-lived, nonfinancial assets be accounted for as a change in accounting
estimate effected by a change in accounting principle. This statement became effective for TVA
beginning in 2007.
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, 2007, and interim periods within
those fiscal years. At this time, TVA is evaluating the requirements of this statement and has not
yet determined the impact of its implementation, which may or may not be material to TVAs results
of operations or financial position.
Accounting for Defined Benefit Pension and Other Postretirement Plans. On September
29, 2006, FASB issued 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
will require employers to fully recognize the obligations associated with single-employer defined
benefit pension, retiree healthcare, and other postretirement plans in their financial statements.
Specifically, the new standard requires an employer to recognize in its statement of financial
position an asset for a plans overfunded status or a liability for a plans underfunded status;
measure a plans assets and its obligations that determine its funded status as of the end of the
employers 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. Those changes will be
reported in comprehensive income of a business entity and in changes in net assets of a
not-for-profit organization.
The requirement to recognize the funded status of a benefit plan and the disclosure
requirements are effective for TVA as of the end of the fiscal year ending after June 15, 2007.
TVA plans to apply the new standard for its September 30, 2007, year-end financial statements and
recognize on its 2007 Balance Sheet the funded status of its pension and other postretirement
benefit plans. However, had TVA been required to adopt the standard as of its last actuarial
valuation date (September 30, 2006), TVA would have recorded the following amounts on its Balance
Sheet for the year then ended: a regulatory asset of $795 million, additional pension and
postretirement obligations of
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$368 million and $152 million, respectively, and the reclassification to regulatory assets of an
intangible asset with a balance of $275 million, representing unamortized prior service cost. The
net effect of recognizing such amounts would have been to increase total assets and liabilities by
$520 million at that date.
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 entitys 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 statement and has not yet determined the
potential impact of its implementation, which may or may not be material to TVAs results of
operations or financial position.
Offsetting Amounts. On April 30, 2007, FASB issued FASB Staff Position (FSP) FASB
Interpretation (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, and 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 TVAs financial position.
Accounting for Misstatements. On September 13, 2006, the Securities and Exchange
Commission issued Staff Accounting Bulletin No. 108, Considering the Effects of Prior Year
Misstatements when Quantifying Misstatements in Current Year Financial Statements. This bulletin
provides interpretive guidance on how the effects of the carryover or reversal of prior year
misstatements should be considered in quantifying a current year misstatement. Application of the
guidance will become effective for TVA with its annual report for the year ending September 30,
2007. TVA is not aware of any potential misstatements at this time.
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 that it believes will be
required to meet future power demand in its service area. Because these amounts are intended to
fund future costs, they were deferred as a regulatory liability. The reserve is funded by power
customers based on a predetermined rate applied to electricity sales approved as part of TVAs 2007
budget. Collections for the nine months ended June 30, 2007, amounted to $52.7 million, and these
amounts are recorded as a regulatory liability on the June 30, 2007 Balance Sheet as a component of
Completed Plant. These and other funds collected for future generation will be amortized
to revenue over the useful lives of the generating assets acquired or constructed in order to match
revenue with the corresponding depreciation expense of these assets on the Statement of Income.
This revenue recognition process will begin when the assets are placed into service.
In December 2006, TVA purchased two combustion turbine facilities for a combined purchase
price of $98 million. One facility is a 742-megawatt winter peaking capacity, dual-fuel combustion
turbine facility and includes certain related transmission facilities. The second facility is a
555-megawatt winter peaking capacity, natural gas-fired combustion turbine facility. The
555-megawatt capacity facility was available for commercial operation in January 2007, and the
742-megawatt facility was available for commercial operation in May 2007. During the second and
third quarters of 2007, depreciation related to the 555-megawatt plant was $0.46 million. During
the third quarter of 2007, depreciation related to the 742-megawatt plant was $0.25 million. TVA
also recognized revenue of $0.71 million during 2007 consistent with the manner in which
the related asset is being depreciated.
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2. Accumulated Other Comprehensive Income
SFAS No. 130, Reporting Comprehensive Income, requires the disclosure of comprehensive
income to reflect changes in capital that result from transactions and economic events from
non-owner sources. The decrease for the three and nine months ended June 30, 2007, the decrease
for the three months ended June 30, 2006, and the increase for the nine months ended
June 30, 2006, were due to unrealized gains and losses related to mark-to-market valuation
adjustments for certain derivative instruments.
Total Other Comprehensive (Loss) Income Activity
Three Months Ended | Nine Months Ended | |||||||||||||||
June 30 | June 30 | |||||||||||||||
2007 | 2006 | 2007 | 2006 | |||||||||||||
Accumulated other comprehensive income at beginning of period |
$ | 6 | $ | 116 | $ | 43 | $ | 27 | ||||||||
Changes in fair value: |
||||||||||||||||
Inflation swap |
0 | (3 | ) | 9 | (8 | ) | ||||||||||
Foreign currency swaps |
(25 | ) | (1 | ) | (71 | ) | 93 | |||||||||
Accumulated other comprehensive (loss) income at end of period |
$ | (19 | ) | $ | 112 | $ | (19 | ) | $ | 112 | ||||||
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 an increase to
earnings of $24 million for the third quarter of 2007 and $81 million for the nine months ended
June 30, 2007, and an increase to earnings of $119 million for the third quarter of 2006 and an
increase to earnings of $110 million for the nine months ended June 30, 2006.
3. Debt Securities
Debt Outstanding
The TVA Act authorizes TVA to issue bonds, notes, and other evidences of indebtedness (debt)
up to a total of $30 billion outstanding at any one time. Debt outstanding at June 30, 2007,
including net translation losses of $276 million related to long-term debt denominated in foreign
currencies, consisted of the following:
Debt Outstanding
At June 30 | At September 30 | |||||||
2007 | 2006 | |||||||
Short-term debt |
||||||||
Discount notes (net of discount) |
$ | 2,610 | $ | 2,376 | ||||
Current maturities of long-term debt |
90 | 985 | ||||||
Total short-term debt, net |
2,700 | 3,361 | ||||||
Long-term debt |
||||||||
Long-term |
20,261 | 19,722 | ||||||
Unamortized discount |
(178 | ) | (178 | ) | ||||
Total long-term debt, net |
20,083 | 19,544 | ||||||
Total outstanding debt |
$ | 22,783 | $ | 22,905 | ||||
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Bond Tests
The TVA Act and the Basic Tennessee Valley Authority Power Bond Resolution each contain two
bond tests: the rate test and the bondholder protection test.
Under the rate test, TVA must charge rates for power which will produce gross revenues
sufficient to provide funds for:
| Operation, maintenance, and administration of its power system; | ||
| Tax equivalents paid to states and counties; | ||
| Debt service on outstanding bonds, notes, and other evidences of indebtedness; | ||
| Payments to the U.S. Treasury as a repayment of and a return on the outstanding amount TVA is required to repay the United States for its investment in TVAs power facilities; and | ||
| Such additional margin as the TVA Board may consider desirable for investment in power system assets, retirement of outstanding bonds, notes, and other evidences of indebtedness in advance of maturity, additional reduction of the outstanding amount TVA is required to repay the United States for its investment in TVAs power facilities, and other purposes connected with TVAs power business, having due regard for the primary objectives of the TVA Act, including the objective that power shall be sold at rates as low as are feasible. |
Under the bondholder protection test, TVA must, in successive five-year periods, use an amount
of net power proceeds at least equal to the sum of:
| The depreciation accruals and other charges representing the amortization of capital expenditures; and | ||
| The net proceeds from any disposition of power facilities; | ||
for either | |||
| The reduction of its capital obligations (including bonds, notes, and other evidences of indebtedness and the outstanding amount TVA is required to repay the United States for its investment in TVAs power facilities); or | ||
| Investment in power assets. |
TVA must next meet the bondholder protection test for the five-year period ending September
30, 2010.
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Long-Term Bond and Note Activity
The table below summarizes TVAs long-term bond and note activity for the period from October
1, 2006, to June 30, 2007.
Long-Term Bond and Note Activity
Date | Amount | Interest Rate | ||||||||
Redemptions/Maturities: |
||||||||||
electronotes® |
First Quarter 2007 | $ | 2 | 4.65 | % | |||||
Second Quarter 2007 | 5 | 4.78 | % | |||||||
Third Quarter 2007 | 5 | 4.79 | % | |||||||
2001 Series D |
December 2006 | 75 | 4.88 | % | ||||||
1997 Series A |
January 2007 | 382 | 6.64 | % | ||||||
Total |
$ | 469 | ||||||||
Issuances: |
||||||||||
electronotes® |
First Quarter 2007 | $ | 9 | 5.50 | % | |||||
Second Quarter 2007 | 19 | 5.29 | % | |||||||
Third Quarter 2007 | 8 | 5.23 | % | |||||||
$ | 36 | |||||||||
Note:
electronotes® interest rate is a weighted average rate.
The 1997 Series A interest rate is the effective swapped interest rate.
4. Risk Management Activities and Derivative Transactions
TVA is exposed to market risks. These market risks include risks related to commodity prices,
investment values, interest rates, currency exchange rates, inflation, and 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 TVAs policy to enter into derivative transactions solely for hedging purposes and not for
speculative purposes.
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The recorded amounts of certain of these derivative instruments are summarized in the table
below.
Mark-to-Market Value of Derivative Instruments
At June 30 | At September 30 | |||||||
2007 | 2006 | |||||||
Inflation Swap |
$ | | $ | 22 | ||||
Interest Rate Swap |
(77 | ) | (131 | ) | ||||
Currency Swaps: |
||||||||
Sterling |
55 | 47 | ||||||
Sterling |
135 | 133 | ||||||
Sterling |
67 | 66 | ||||||
Swaptions: |
||||||||
$1 Billion Notional |
(221 | ) | (296 | ) | ||||
$28 Million Notional |
(1 | ) | (3 | ) | ||||
$14 Million Notional |
(1 | ) | (2 | ) | ||||
Coal Contracts with Volume Options |
36 | 487 | ||||||
Purchase Power Option Contracts |
(1 | ) | (22 | ) |
TVA has a financial trading program under which TVA can purchase swaps, options on swaps,
futures, and options on futures to hedge TVAs exposure to natural gas and fuel oil prices. At
June 30, 2007, TVA had derivative positions outstanding under the program equivalent to 5,613
contracts, made up of 1,915 futures contracts and 3,698 swap futures contracts, with an approximate
net market value of $201 million, as shown in the following table.
Financial Trading Program Activity
Three Months Ended | Nine Months Ended | |||||||||||||||
June 30, 2007 | June 30, 2007 | |||||||||||||||
Notional | Contract | Notional | Contract | |||||||||||||
Amount | Value | Amount | Value | |||||||||||||
(in mmBtu) | (in millions) | (in mmBtu) | (in millions) | |||||||||||||
Futures contracts |
||||||||||||||||
Financial positions, beginning of period, net |
4,090,000 | $ | 31 | 4,290,000 | $ | 35 | ||||||||||
Purchased |
25,470,000 | 202 | 32,050,000 | 251 | ||||||||||||
Settled |
(10,410,000 | ) | (76 | ) | (17,190,000 | ) | (125 | ) | ||||||||
Realized (losses) |
| (4 | ) | | (8 | ) | ||||||||||
Net positions-long |
19,150,000 | 153 | 19,150,000 | 153 | ||||||||||||
Swap Futures |
||||||||||||||||
Financial positions, beginning of period, net |
| | 1,822,500 | 11 | ||||||||||||
Fixed portion |
9,245,000 | 70 | 9,632,500 | 73 | ||||||||||||
Floating
portion - realized |
| | (2,210,000 | ) | (12 | ) | ||||||||||
Realized (losses) |
| | | (2 | ) | |||||||||||
Net positions-long |
9,245,000 | 70 | 9,245,000 | 70 | ||||||||||||
Holding gains (losses) |
||||||||||||||||
Unrealized gain (loss) at beginning of period, net |
| 2 | | (6 | ) | |||||||||||
Unrealized (loss) for the period |
| (24 | ) | | (16 | ) | ||||||||||
Unrealized (losses) at end of period, net |
| (22 | ) | | (22 | ) | ||||||||||
Financial positions at end of period, net |
28,395,000 | $ | 201 | 28,395,000 | $ | 201 | ||||||||||
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For the three and nine months ended June 30, 2007, TVA recognized realized losses of about
$4 million and $10 million, respectively, which were recorded as an increase to purchased power
expense. Unrealized losses at June 30, 2007, totaled about $22 million, representing a change of
$24 million for the third quarter. TVA deferred the $22 million unrealized loss as a regulatory
asset in accordance with its new 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.
5. Benefit Plans
TVA sponsors a defined benefit pension plan that covers most of its full-time employees, 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
Pension Benefits | Other Benefits | Pension Benefits | Other Benefits | |||||||||||||||||||||||||||||
Three Months Ended | Three Months Ended | Nine Months Ended | Nine Months Ended | |||||||||||||||||||||||||||||
June 30 | June 30 | June 30 | June 30 | |||||||||||||||||||||||||||||
2007 | 2006 | 2007 | 2006 | 2007 | 2006 | 2007 | 2006 | |||||||||||||||||||||||||
Service cost |
$ | 30 | $ | 32 | $ | 1 | $ | 2 | $ | 90 | $ | 95 | $ | 4 | $ | 6 | ||||||||||||||||
Interest cost |
123 | 110 | 8 | 8 | 369 | 330 | 20 | 22 | ||||||||||||||||||||||||
Expected return on plan assets |
(142 | ) | (123 | ) | | | (428 | ) | (368 | ) | | | ||||||||||||||||||||
Amortization of prior service costs |
9 | 9 | 2 | 1 | 27 | 27 | 4 | 4 | ||||||||||||||||||||||||
Amortization of losses |
20 | 33 | | 4 | 61 | 99 | 4 | 12 | ||||||||||||||||||||||||
Net periodic benefit |
$ | 40 | $ | 61 | $ | 11 | $ | 15 | $ | 119 | $ | 183 | $ | 32 | $ | 44 | ||||||||||||||||
The TVA Board approved $75 million in pension contributions for 2007, with scheduled
contributions of $38 million and $37 million to be made in March and September, respectively.
During the nine months ended June 30, 2007, TVA made $38 million in contributions to its pension
plan. TVA does not separately set aside assets to fund benefit costs other than pensions, but
rather funds such costs on an as-paid basis. TVA provided approximately $13 million during the nine
months ended June 30, 2007, to fund these other benefits costs.
6. Project Write-Downs
During the first nine months of 2007, TVA recognized write-downs totaling $23 million in
Operating and Maintenance expense on TVAs Statement of Income. These write-downs,
related to certain construction work in progress assets, were due to the cancellation and deferral
of certain projects. The largest write-down was $17 million for the deferral of the flue gas
desulphurization (scrubber) project at Unit 5 of TVAs Colbert Fossil Plant (Colbert Unit 5),
originally intended to be built in 2010. The scheduling of certain clean-air projects has shifted,
resulting in the deferral of the Colbert Unit 5 scrubber project until 2015. Because of the
extended deferral period, TVA charged the capitalized costs to earnings based on the uncertainty of
future benefit that would be realized from the work completed thus far once the project is
ultimately completed.
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7. 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 $22 million with respect
to the proceedings described below as of June 30, 2007, as well as approximately $6 million with
respect to other proceedings that have arisen in the normal course of TVAs business. No assurance
can be given that TVA will not be subject to significant additional claims and liabilities. If
actual liabilities significantly exceed the estimates made, TVAs results of operations, liquidity,
and financial condition could be materially adversely affected.
Economy Surplus Power Case
On August 31, 1999, suit was filed against TVA in the United States District Court for the
Northern District of Alabama by Birmingham Steel Corporation, on behalf of itself and a class of
TVA industrial customers that contracted for economy surplus power. While Birmingham Steel
Corporation was the original class representative, it filed for bankruptcy and was excluded from
the class. Johns Manville Corporation was substituted as the class representative. The lawsuit
alleges that TVA overcharged for economy surplus power during the summer of 1998 by improperly
including some incremental costs when calculating the price of economy surplus power. The class
members seek over $100 million in damages. On April 18, 2006, the district court ruled on motions
for summary judgment filed by both sides. The court held that TVA improperly included charges for
approximately 500 hours of power purchased in advance and breached the contracts. The court
rejected TVAs position that the additional price charged for all hours represented actual
incremental costs incurred by TVA in supplying economy surplus power and thus was an appropriate
part of the economy surplus power contract price. The court granted the plaintiffs motion for
summary judgment on liability, even though it acknowledged that there are disputed factual issues
as to TVAs defenses. On July 31, 2006, the court reconsidered its decision on summary judgment
with respect to TVAs affirmative defenses and held that TVA is entitled to a trial on its
affirmative defenses. The parties engaged in mediation in December 2006. The parties have reached
a settlement agreement under which TVA will pay approximately $18 million to resolve the case. To
be effective, the settlement must be approved by the United States District Court of the Northern
District of Alabama. The settlement was submitted to the court on May 21, 2007, and the court
preliminarily approved it on June 6, 2007. There is a 45 day period during which objections to the
settlement may be filed, and a hearing on the fairness of the settlement has been scheduled for
August 20, 2007.
Case Against TVA and 22 Electric Cooperatives
On December 2, 2004, the United States District Court for the Middle District of Tennessee
dismissed a lawsuit filed by John McCarthy, Stan Cooper, Joe Sliger, Mike Bell, Don Rackley, Terry
Motley, Billy Borchert, Jim Foster, and Ryan Hargis on behalf of themselves and all others
similarly situated against TVA and the Middle Tennessee Electric Membership Cooperative,
Appalachian Electric Cooperative, Caney Fork Electric Corporation, Inc., Chickasaw Electric
Cooperative, Cumberland Electric Membership Corporation, Duck River Electric Membership
Corporation, Fayetteville Public Utilities, Forked Deer Electric Cooperative, Inc., Fort Loudoun
Electric Cooperative, Gibson Electric Membership Corporation, Holston Electric Cooperative, Inc.,
Meriwether Lewis Electric Cooperative, Mountain Electric Cooperative, Inc., Pickwick Electric
Cooperative, Plateau Electric Cooperative, Powell Valley Electric Cooperative, Sequachee Valley
Electric Cooperative, Southwest Tennessee Electric Membership Corporation, Tennessee Valley
Electric Cooperative, Tri-County Electric Membership Corporation, Tri-State Electric Membership
Corporation, Upper Cumberland Electric Membership Corporation, and Volunteer Energy Cooperative.
The lawsuit in part challenged TVAs practice of setting rates for electric power charged by
distributor customers through TVAs contracts with distributor customers. In granting the
defendants motions to dismiss, the court held that the claims alleging violations of state law
failed because the plaintiffs (consisting of Tennessee residents and customers of certain of the
cooperatives) had not completed the steps necessary to bring these claims in court.
With respect to the claim against TVA, the court held that the alleged violations of federal
law failed as a matter of law because Congress had specifically authorized TVA to set the rates
charged by distributor customers through TVAs contracts with distributor customers. The plaintiffs
appealed to the United States Court of Appeals for the Sixth Circuit (Sixth Circuit), and on
October 17, 2006, the Sixth Circuit affirmed the district courts decision, holding, among other
things, that TVAs rates were not subject to judicial review and that TVA is not subject to
antitrust liability when doing so would interfere with TVAs purposes.
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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 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 carbon dioxide
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 U.S.
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 Courts decision in
Massachusetts v. EPA, 127 S.Ct. 1438 (2007), on the issues raised by the parties, and 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 TVAs Colbert Fossil Plant, a coal-fired electric generating facility located in
Tuscumbia, Alabama. The plaintiffs allege that TVA made major modifications to one of the power
generating units, specifically 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 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 U.S. Court of Appeals for the Eleventh Circuit (Eleventh Circuit) on January 25, 2006.
Briefing of the appeal to the Eleventh Circuit was completed in July 2006. Oral argument of the
appeal was held on January 11, 2007. If the decision is reversed on appeal, there is a reasonable
possibility that TVA will be ordered to install additional controls on Colbert Unit 5.
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 TVAs motion to dismiss the lawsuit on statute of limitation
grounds. The plaintiffs motion for reconsideration was denied, and they appealed to the Sixth
Circuit. Amicus curiae 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 an amicus curiae 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. The
Sixth Circuit has not yet acted on TVAs request. However, TVA is already installing or has
installed the control equipment that plaintiffs seek to require of TVA in this case, and it is
unlikely that an adverse decision will result in substantial additional costs to TVA.
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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 Alabamas 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 courts
decision to the Eleventh Circuit. On November 22, 2005, the Eleventh Circuit affirmed the district
courts 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. These motions have been fully briefed and are awaiting decision. On April
12, 2007, EPA proposed to approve Alabamas de minimis rule subject to certain changes. This
rulemaking proceeding is ongoing. On July 16, 2007, the district court denied TVAs motion to stay
the proceedings pending approval of Alabamas de minimis rule. A decision on the motion for
summary judgment is anticipated to be issued in the near future.
Case Brought by North Carolina Alleging Public Nuisance
On January 30, 2006, North Carolinas Attorney General filed suit against TVA in the United
States District Court for the Western District of North Carolina alleging that TVAs operation of
its coal-fired power plants in Tennessee, Alabama, and Kentucky constitute public nuisances. 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 TVAs 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 TVAs 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 appeal
to the Fourth Circuit was completed in January 2007. The oral argument before the Fourth Circuit,
which had been scheduled for September 2007, has been postponed and has not yet been rescheduled.
On July 2, 2007, North Carolina filed a motion for partial summary judgment addressing certain of
TVAs defenses. The trial before the district court previously scheduled for the term of court
beginning October 2007 has been rescheduled for the term of court beginning after January 2008.
Case Involving North Carolinas 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 and nitrogen oxides emitted by
coal-fired power plants in 13 states, including states where TVAs 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 EPAs decision with the United States Court of Appeals for the District of Columbia
Circuit. Briefing on the appeal is underway.
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 Katrinas increased destructive force. The
plaintiffs are seeking monetary damages among other relief. TVA has moved to dismiss the complaint
on grounds that TVAs 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 is scheduled to hear
oral arguments on whether the issue of greenhouse gas emissions is a political matter which should
not be decided by the court.
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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 (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. After
agreeing to become Warrens power supplier, East Kentucky 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.
(With the exception of wheeling power to Bristol, Virginia, the anti-cherrypicking provision
precludes TVA from being ordered to wheel another suppliers power to a customer if the power would
be consumed within TVAs defined service territory.) 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 to provide the
interconnections, 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 Kentuckys 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 December 7, 2006, Warren announced its intention to
withdraw its notice to terminate its existing power contract. On January 10, 2007, TVA and Warren
executed an agreement under which Warren rescinded its notice of termination and the parties
extended the term of the TVA power contract through June 11, 2016. Given this agreement, East
Kentucky no longer needs to establish interconnections to TVAs transmission system and 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.
Whether or not FERC grants TVAs motion to vacate, it is likely that the FERC proceeding and the
resulting litigation will eventually be dismissed and not proceed to a conclusion.
Claim 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
provided fuel fabrication services for TVAs Bellefonte Nuclear Plant. AREVAs 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 Officers 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 response to the complaint on June 15, 2007. TVA is currently
awaiting a schedule in the case and the beginning of discovery.
Notification of Potential Liability for Ward Transformer Site
TVA has been notified by one of the parties involved with clean-up of the Ward Transformer
(Ward) Superfund Site, a facility located in Raleigh, North Carolina, that it considers TVA a
potentially responsible party and intends to pursue a claim against TVA. The Ward site is one of
two non-TVA areas identified in TVAs Annual Report for which TVA was unable to estimate its
potential liability. 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. There is evidence that in the summer of
1974 TVA sent transformers to Ward that contained polychlorinated biphenyls (PCBs). Several
responsible parties have entered into a settlement agreement with EPA to clean up on-site
contamination at the site, and the cost of the on-site cleanup is currently estimated to be $20
million. EPA is also investigating off-site contamination from Ward operations, which may extend
to the Neuse River and includes water bodies in a county and state park. The State of North
Carolina has issued fish consumption advisories due to PCBs in areas up to 20 miles downstream of
the Ward site. The expansion of the area believed to have been contaminated offsite and the
potential for assessments of natural resource damages to liable parties could substantially raise
the cleanup costs. As yet there is no formal estimate of the costs associated with this site or
any potential damages. It is unknown at this time what level of liability, if any, TVA will have
in these matters, whether it will be required to contribute, and, if so, how much such a
contribution would be.
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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. Adverse outcomes in these proceedings would not normally
be material to TVAs 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.
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 TVAs
failure to properly maintain duct work at Widows Creek Unit 7. From 2002 to 2005, the units
ducts allowed sulfur dioxide to escape into the air. TVA repaired the duct work 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.
Significant Litigation to Which TVA Is Not a Party
On April 2, 2007, in Massachusetts v. EPA, a case concerning whether EPA has the authority and
duty to regulate carbon dioxide emissions under the CAA, the Supreme Court found that greenhouse
gases, including carbon dioxide, are pollutants under the CAA and thus EPA does have the authority
to regulate these gases. The Supreme Court also concluded that EPAs refusal to regulate these
pollutants was based on impermissible reasons, and remanded the case to EPA to ground its reasons
for action or inaction in the statute. While this case focused on carbon dioxide emissions from
motor vehicles, it sets a precedent for regulation in other industrial sectors, such as the
electric utility industry.
On April 2, 2007, the Supreme Court also 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
EPAs 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 under EPAs 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.
TVA is currently involved in two NSR cases (one involving Bull Run and another at Colbert).
These cases are discussed in more detail above. The Supreme Courts rejection of the hourly
standard for emissions testing could undermine one of TVAs 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
Courts 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.
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8. Subsequent Events
Debt Securities
In July 2007, TVA issued $1 billion of its 2007 Series A Power Bonds with an interest rate of
5.50 percent and a maturity date of July 18, 2017.
Financial Trading Program
On August 1, 2007, the TVA Board expanded the Financial Trading Program, among other things,
(1) to permit financial trading for the purpose of hedging or otherwise limiting the economic risks
associated with the price of electricity, coal, emission allowances, nuclear fuel, and other
commodities such as ammonia and limestone, as well as the price of natural gas and fuel oil, (2) to
authorize the use of futures, swaps, options, and combinations of these instruments as long as
these instruments are standard in the industry, (3) to use the Intercontinental Exchange as well as
the New York Mercantile Exchange to trade financial instruments, and (4) to increase the aggregate
transaction limit to $130 million (based on one-day Value at Risk). Under the expanded program,
TVA is still prohibited from trading financial instruments for speculative purposes. See Note 4.
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ITEM 2. MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Dollars in millions except where noted)
(Dollars in millions except where noted)
Managements Discussion and Analysis of Financial Condition and Results of Operations (MD&A)
explains the results of operations and general financial condition of the Tennessee Valley
Authority (TVA). The MD&A should be read in conjunction with the accompanying financial
statements and TVAs Annual Report, as amended, on Form 10-K/A for the fiscal year ended September
30, 2006 (the Annual Report).
Business Overview
Financial Outlook
As of June 30, 2007, TVAs net income for 2007 is forecasted to be about $31 million, or 7.0
percent, less than budgeted, primarily because of unseasonable winter weather and dry conditions in
the Tennessee Valley during the first nine months of 2007. Power sales are 2.2 percent below
budgeted amounts for the nine months ended June 30, 2007, as a result of decreased demand primarily
due to weather. Hydroelectric generation, TVAs cheapest source of power, is 32 percent below
budget for the nine months ended June 30, 2007, primarily due to dry conditions.
Additionally, the six-month period of January through June was the second driest on record in
the eastern Tennessee Valley in 118 years. Rainfall was 56 percent of normal, and runoff was 47
percent of normal for the eastern Tennessee Valley during this six-month period. It is assumed
that the dry conditions will continue throughout the remainder of the year. As a result of low
rainfall and runoff, TVA began conserving water in early winter to help ensure sufficient
quantities were available to meet the multiple reservoir operating objectives through the summer
months.
The effects of the weather on sales, additional purchased power due to more outage days, and
lower rated electrical capabilities of generating equipment (deratings), along with higher fuel
prices have increased TVAs delivered cost of power per unit sold in 2007. Additionally, these
factors contributed to a lower balance of cash and cash equivalents on hand as of June 30, 2007, as
compared to September 30, 2006. TVAs cash flow from operations was down $106 million, or nine
percent, for the nine months ended June 30, 2007, primarily due to the timing of the collection of
revenues related to the fuel cost adjustment. In response, management has identified cost
reductions in operating and maintenance activities to be implemented over the remainder of the
year.
Strategic Plan
On May 31, 2007, the TVA Board of Directors (TVA Board) approved a new strategic plan for
TVA. The 2007 Strategic Plan (the Plan) outlines the Boards policy-level direction and strategy
for TVA over the next decade and highlights several actions that are needed for successful
implementation of that strategy. It is anticipated that the Plan will be updated, as needed, based
on changing market conditions.
Development of the Plan was guided by an examination of TVAs current business environment and
assessments of what TVA might expect in its future operational, economic, and regulatory climate.
In developing the Plan, the TVA Board determined that TVAs current business structure best enables
TVA to carry out its integrated mission. The Plan proposes to largely preserve the current
structure but adapt it to todays competitive environment. Key components of the business structure
outlined in the Plan are listed below.
| Focus will continue on a three-part integrated mission in energy, the environment, and economic development. | ||
| All aspects of the business area will continue to be funded from power revenues and financings. | ||
| Generation and transmission services will continue to be provided as part of a bundled package. | ||
| Demand for power will be met through a careful balance of self-reliance and partnership with others, limiting dependence on the market to keep costs competitive and reduce risk associated with short-term market volatility. | ||
| Financing obligations will be appropriate to the value of the assets. |
In the context of TVAs business structure, the Plan identifies five broad strategic
objectives on which TVA will focus as it moves forward, and several corresponding critical success
factors that support those objectives. Objectives include the following items:
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| Customers: Maintain power reliability, provide competitive rates, and build trust with TVAs customers. | ||
| People: Build pride in TVAs performance and reputation. | ||
| Financial: Adhere to a set of sound financial guiding principles to improve TVAs fiscal performance. | ||
| Assets: Use TVAs assets to meet market demand and deliver public value. | ||
| Operations: Improve performance to be recognized as an industry leader. |
The Plan identifies corporate-level metrics which will be used to monitor TVAs performance
toward achieving successful implementation of the strategic objectives. These metrics will be
reviewed and systematically updated to maintain alignment with strategic focus. They include:
Customers Competitive performance will be measured by:
| Customer point interruptions | ||
| Customer satisfaction index | ||
| Delivered cost of power | ||
| Participation in energy efficiency and peak-shaving initiatives | ||
| Economic development index |
People Workforce performance will be measured by:
| Recordable-injury rate | ||
| Cultural health index |
Financial Fiscal health and performance will be measured by:
| Ratio of debt and debt-like obligations to asset value | ||
| Ratio of earnings to asset value | ||
| Productivity |
Assets & Operations Operational performance will be measured by:
| Equivalent availability of generation | ||
| Megawatt demand reduction | ||
| Environmental performance |
New Generation
In order to help balance the use of purchased power and its own generation to meet growing
power supply needs in its service area, TVA purchased two additional combustion turbine facilities
in December 2006, totaling approximately 1,200 megawatts. The Gleason facility was available for
commercial operation in January 2007 and the Marshall County Facility in May 2007.
Browns Ferry Nuclear Plant Unit 1 (Browns Ferry Unit 1) began commercial operation on August
1, 2007. The cost of the project as of June 30, 2007, was $1.81 billion excluding allowance for
funds used during construction (AFUDC) of $260 million and asset retirement obligation costs.
The cost was slightly more than TVAs original estimate because of steam dryer modifications, the
selection of Browns Ferry Unit 1 as the lead plant for extended power up-rate, and schedule
adjustments that optimize timing with the Browns Ferry Nuclear Plant Unit 2 refueling outage.
Browns Ferry Unit 1 is expected initially to provide additional generating capacity of
approximately 1,150 megawatts and eventually to provide 1,280 megawatts of capacity.
On August 1, 2007 the TVA Board approved the completion of Watts Bar Nuclear Plant Unit 2
(Watts Bar Unit 2) upon which construction was halted in 1985. Prior to the decision, TVA
conducted a detailed scoping, estimating, and planning study to estimate the projects cost,
schedule, and risks. Separately, TVA has prepared a report evaluating potential environmental
impacts as required by the National Environmental Policy Act. TVA has a construction permit from
the Nuclear Regulatory Commission (NRC) for Watts Bar Unit 2 that expires in 2010 and will need
to seek an extension of its construction permit in order to complete construction activities. TVA
will seek an operating license under NRC regulations, including an opportunity for a public
hearing. Completing Watts Bar Unit 2
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is expected to take 60 months and cost approximately $2.49 billion, excluding allowance for funds
used during construction and initial nuclear fuel core costs. When completed, the nuclear unit is
expected to provide 1,180 megawatts of electricity. Some activities at the site are expected to
begin October 1, 2007. On August 3, 2007, TVA notified the NRC of its plan to resume unlimited
construction activities on December 3, 2007.
In the third quarter of 2007, TVA entered into a definitive agreement for the purchase of the
Tenaska-Haywood combustion turbine site located in southwest Tennessee. Originally planned as a
peaking facility, this approximately 80 acre site was not completed but contains turbine
foundations and substantial ancillary equipment. The combustion turbines were previously
acquired and relocated by another purchaser. TVA is currently
exploring the possibility of repowering the site as a combined cycle
combustion turbine facility. Closing of this acquisition is presently
aniticipated for October 2007.
In addition, during the third quarter of 2007, TVA entered into an operating lease agreement
and various related contracts for the Caledonia combined-cycle facility located near Columbus,
Mississippi, with a commencement date of July 1, 2007. The lease agreement has a 15-year term
expiring on February 28, 2022. The Caledonia combined-cycle facility consists of three
combined-cycle units with a nominal capacity of 813 megawatts and a capacity of 750 megawatts in
the summer. A conversion services agreement providing for power purchases from the Caledonia
facility was terminated as of July 1, 2007, the lease commencement date, and dispatch control was
shifted to TVA on July 3, 2007. Under the lease, TVA will assume plant operations management
effective January 1, 2008. The lease agreement further provides for an end-of-term purchase
option.
TVA is also working with distributor customers to explore distributor ownership and
development opportunities that may exist related to power generation facilities. Such agreements
may potentially provide new sources of power for use in meeting power demand in the areas served by
TVA and distributors of TVA power in addition to the actions reported above. In July 2007, a large
group of distributors formed Seven States Power Corporation, a Tennessee nonprofit corporation, to
further this effort.
Customers
On May 31, 2007, the TVA Board approved a new interruptible pricing product for commercial and
industrial customers. The new product, called Five-Minute Response Power (5 MR), was developed
with input from power distributors and TVAs directly served customers. Customers on interruptible
products agree to have their power interrupted at various times, such as when the demand for power
is high and the TVA power supply is tight. Customers that move to the new product will receive a
credit on their firm power rates for the portion of their loads that TVA may interrupt. TVA has set
the monthly credit at $4 for each kilowatt-hour of the customers interruptible load for the month.
Interruptible power products, such as 5 MR, also may allow TVA to avoid building some additional
generation. This product is being introduced as a part of the transition to a new portfolio of
pricing products for large commercial and industrial customers.
Service Reliability
Continuing dry conditions may have further impact on TVAs operations for the remainder of the
fiscal year in several areas. There may be a loss of hydroelectric generation due to balancing
water for generation with potential summer reliability thermal issues related to the temperature of
cooling water discharged from fossil plants. To a lesser degree, low water levels may result in
constrained deliveries of fuel by barge. TVA management continues to review these issues and to
assess its plans for the anticipated increased electricity demand during the summer months.
In addition, TVA has participated in meetings to address deficiencies in hydroelectric
production on the Cumberland River due to safety issues resulting from increased seepage rates at
the U.S. Army Corps of Engineers Wolf Creek Dam. In light of these safety issues, the
Southeastern Power Administration (SEPA) has not been able to provide TVA and other customers
with all of the power that it is required to provide under its contractual arrangements with these
parties. SEPAs performance under these arrangements will continue to be monitored to assess how
the deficiencies in hydroelectric production will affect TVA and other customers with an interest
in the output of the Cumberland River system. As events at these non-TVA bodies of water or their
associated hydroelectric facilities have interfered with the flow of water, TVA has been required
to temporarily reduce power output at some fossil plants along the Cumberland River.
The planned outage of Unit 3 at TVAs Paradise Fossil Plant to correct an issue with a turbine
rotor was originally scheduled to begin on March 17, 2007, and to be completed on April 29, 2007.
Due to more extensive repairs identified during the outage, the unit did not return to service
until June 7, 2007. During this additional period,
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the plants generation was reduced by 1,026 megawatts. The current estimate is that TVA
incurred $7 million in unplanned repair costs, and an additional $25 million in replacement power
purchase costs.
A new era of mandatory compliance with reliability standards began on June 18, 2007. The
Federal Energy Regulatory Commission (FERC) issued its final rule on the Electric Reliability
Organization (ERO) Reliability Standards approving 83 of 107 proposed standards submitted by the
North American Electric Reliability Corporation. The mandatory reliability standards apply to all
users, owners, and operators of the bulk power system, including TVA, and both monetary and
non-monetary penalties may be imposed for violations of the standards. The most serious violations
can be subject to penalties of up to $1 million per day per violation. The rule directs the ERO to
focus on the most serious violations during an initial period through December 31, 2007. TVA is
not operating with any known violations.
Load flow studies for the southern extreme of TVAs Mississippi service area indicate that for
both periods of light and heavy load there are multiple contingencies that produce low voltages,
overloads, or even local blackouts. A new interconnection, the Five Points-Homewood
interconnection project, was established with South Mississippi Electric Power Association on July
3, 2007. This project was implemented to address these contingencies and avoid the possible load
shed of approximately 280 megawatts. This interconnection is the first with a neighboring utility
since 1993. TVA now has interconnections with 13 neighboring electric systems.
Performance Improvement Initiative
Among the keys to successful implementation of TVAs operations strategy is the reduction of
expenses and prevention of non-fuel expenses from growing faster than sales. TVA intends to
achieve top-quartile performance in non-fuel operations and maintenance expenses and limit the
growth of these expenses through its recently implemented performance improvement initiative.
Under this initiative, TVA plans to be in the top quartile in non-fuel operations and maintenance
expenditure performance within three years. Achieving this goal will require TVA to reduce
non-fuel operations and maintenance expenses relative to total generating capacity, megawatt-hours
sold, and rate of sales growth. Meeting these goals should significantly affect TVAs ability to
achieve certain critical success factors identified in the 2007 Strategic Plan.
Increased Fuel and Purchased Power Costs
In July 2006, the TVA Board approved the implementation of a fuel cost adjustment (FCA) to
be applied quarterly, beginning on October 1, 2006, as a mechanism to adjust TVAs rates to reflect
changing fuel and purchased power costs from the amounts included in TVAs base rates. Due to the
revised forecasts for the third quarter of 2007, the adjustment implemented on July 1, 2007, was an
increase of 0.087 cents per kilowatt-hour and is expected to produce an estimated $38.5 million in
revenue during the fourth quarter of 2007. The FCA had no effect on rates prior to January 1,
2007. The FCA was initially set to zero and had its first impact on rates beginning January 1,
2007, at which time rates increased 0.01 cents per kilowatt-hour. As of June 30, 2007, TVA had
recognized a regulatory asset of $110 million representing deferred power costs to be recovered
through the FCA adjustments in future periods.
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Liquidity and Capital Resources
Sources of Liquidity
TVAs 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. TVAs 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 TVAs $150 million note with the U.S. Treasury.
Other sources of liquidity include two $1.25 billion credit facilities with a national bank as well
as occasional proceeds from other financing arrangements including call monetization transactions
and sales of receivables and loans.
Summary Cash Flows. A major source of TVAs liquidity is operating cash flows resulting from
the generation and sales of electricity. A summary of cash flow components for the nine months
ended June 30, 2007, and 2006, follows:
Summary Cash Flows
For the Nine Months Ended June 30
For the Nine Months Ended June 30
2007 | 2006 | |||||||
Cash provided by (used in) |
||||||||
Operating activities |
$ | 1,112 | $ | 1,218 | ||||
Investing activities |
(1,246 | ) | (1,233 | ) | ||||
Financing activities |
(265 | ) | (22 | ) | ||||
Net decrease in cash and cash
equivalents |
$ | (399 | ) | $ | (37 | ) | ||
Issuance of Debt. TVA issued $36 million of power bonds during the nine months ended June
30, 2007, while redeeming $469 million of power bonds. In July 2007, TVA issued $1 billion of its
2007 Series A Power Bonds with an interest rate of 5.50 percent and a maturity date of July 18,
2017. For more information regarding TVAs debt activities, see Note 3.
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 November 11, 2007, and one which matures on May 14, 2008. The interest rate on any
borrowing under either of these facilities is variable and based on market factors and the rating
of TVAs 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 TVAs senior unsecured long-term
debt. There were no outstanding borrowings under the facilities at June 30, 2007. TVA anticipates
renewing each credit facility from time to time.
Comparative Cash Flow Analysis
Net cash provided by operating activities decreased $106 million from $1,218 million to $1,112
million for the nine months ended June 30, 2006, and 2007, respectively. This decrease resulted
primarily from:
| An increase in cash paid for fuel and purchased power of $159 million due to higher volume of fuel and purchased power as well as increased market prices for fuel; | ||
| An increase in cash outlays for routine and recurring operating costs of $69 million; | ||
| An increase in tax equivalent payments of $47 million; | ||
| An increase in expenditures for nuclear refueling outages of $31 million due to three planned outages in the first nine months of the current year compared to two planned outages in the prior year; | ||
| A $57 million larger decrease in accrued interest due to the timing of payments and interest expense differences between bonds which matured and bonds which were issued; and | ||
| A $119 million decrease in accounts payable and accrued liabilities in the first nine months of 2007 compared to a $20 million increase in these items in the same period of 2006 primarily due to changes in the amount of collateral held by TVA of $83 million under terms of a swap agreement and the timing of accruals for fuel acquired in 2006 and paid for in 2007. |
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These items were partially offset by:
| An increase in cash provided by operating revenues of $260 million resulting primarily from higher average rates and increased demand from municipalities and cooperatives due to an increase in combined weather degree days; | ||
| A decrease in cash interest of $37 million in the first nine months of 2007; and | ||
| An increase in the collection of accounts receivable of $74 million primarily due to increased rates and slightly increased volume over the prior year. |
Cash used in investing activities increased $13 million from the first nine months of 2006 to
the first nine months of 2007. The increase was primarily due to:
| An increase in expenditures of $94 million for capital projects primarily due to increased expenditures of $70 million related to the Watts Bar Steam Generator Replacement project, an increase of $78 million related to the Kingston Scrubber addition, and a corresponding increase of $25 million in AFUDC, partially offset by a decrease of $98 million for the Browns Ferry Unit 1 restart; and | ||
| An increase in expenditures of $100 million primarily to acquire the Gleason and Marshall County combustion turbine facilities. |
These items were partially offset by:
| A decrease in expenditures for the enrichment and fabrication of nuclear fuel of $86 million related to the restart of Browns Ferry Unit 1; and | ||
| A $14 million reduction in the amount of restricted cash and investments held by TVA during the first nine months of 2007 compared to a $71 million increase in the amount of restricted cash and investments held by TVA during the same period of 2006. |
Net cash used in financing activities increased $243 million from the first nine months of
2006 to the first nine months of 2007 primarily due to:
| A decrease of $1,069 million in long-term debt issuances; and | ||
| An increase in redemptions and repurchases of long-term debt of $310 million. |
These items were partially offset by an increase in net issuances of short-term debt of $1,128
million in the first nine months of 2007 compared to the same period in the prior year.
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Cash Requirements and Contractual Obligations
The estimated cash requirements and contractual obligations for TVA as of June 30, 2007, are
detailed in the following table.
Commitments & Contingencies
Total | 2007 (1) | 2008 | 2009 | 2010 | 2011 | Thereafter | ||||||||||||||||||||||
Debt (2) |
$ | 22,220 | $ | 2,610 | $ | 90 | $ | 2,030 | $ | 62 | $ | 1,015 | $ | 16,413 | ||||||||||||||
Interest payments relating to debt |
20,690 | 187 | 1,174 | 1,118 | 1,063 | 1,032 | 16,116 | |||||||||||||||||||||
Leases |
||||||||||||||||||||||||||||
Non-cancelable operating |
439 | 16 | 63 | 49 | 37 | 28 | 246 | |||||||||||||||||||||
Capital |
211 | 2 | 59 | 58 | 57 | 29 | 6 | |||||||||||||||||||||
Power purchase obligations |
5,081 | 60 | 164 | 182 | 185 | 185 | 4,305 | |||||||||||||||||||||
Purchase obligations |
||||||||||||||||||||||||||||
Fuel purchase obligations |
3,215 | 879 | 565 | 503 | 483 | 223 | 562 | |||||||||||||||||||||
Other obligations |
466 | 59 | 265 | 125 | 8 | 2 | 7 | |||||||||||||||||||||
Payments on other financings |
1,492 | 20 | 89 | 85 | 89 | 95 | 1,114 | |||||||||||||||||||||
Payment to the U.S. Treasury (3) |
||||||||||||||||||||||||||||
Return of appropriation investment |
150 | 20 | 20 | 20 | 20 | 20 | 50 | |||||||||||||||||||||
Return on appropriation investment |
282 | 20 | 23 | 22 | 21 | 20 | 176 | |||||||||||||||||||||
Retirement plans |
44 | 44 | | | | | | |||||||||||||||||||||
Total |
$ | 54,290 | $ | 3,917 | $ | 2,512 | $ | 4,192 | $ | 2,025 | $ | 2,649 | $ | 38,995 | ||||||||||||||
Notes: | ||
(1) | Period July 1 - September 30, 2007. | |
(2) | Does not include noncash items of foreign currency valuation loss of $276 million and unamortized discount of $178 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. Interest is accrued daily at a rate determined by the United States Secretary of the Treasury each month based on the average rate on outstanding marketable obligations of the United States with maturities of one year or less. During 2006, the daily average outstanding balance was $131 million. TVAs 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 June 30, 2007. Accordingly, the Commitments and Contingencies table does not include any outstanding payment obligations to the U.S. Treasury for this note at June 30, 2007. |
In addition to the cash requirements above, TVA has contractual obligations to provide
power related to energy prepayments. See Note 1 Energy Prepayment Obligations.
Total | 2007* | 2008 | 2009 | 2010 | 2011 | Thereafter | ||||||||||||||||||||||
Energy prepayment obligations |
$ | 1,165 | $ | 27 | $ | 106 | $ | 105 | $ | 105 | $ | 105 | $ | 717 | ||||||||||||||
Note: | ||
* Period July 1 - September 30, 2007. |
Bear Creek Dam, a small flood-control, non-generating dam in northern Alabama is
experiencing foundation problems as evidenced by seepage through the foundation of the dam. An
Environmental Impact Statement is expected to be final in August 2007 with the preferred
alternative being to repair the dam. The estimated cost to repair the dam is approximately $35
million. Additional detailed engineering and site work is currently underway to verify the
estimated repair cost.
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Results of Operations
Financial Results
The following table compares operating results and selected statistics for the three and nine
months ended June 30, 2007, and 2006.
Summary Statements of Income
Three Months Ended | Nine Months Ended | |||||||||||||||
June 30 | June 30 | |||||||||||||||
2007 | 2006 | 2007 | 2006 | |||||||||||||
Operating revenues |
$ | 2,236 | $ | 2,242 | $ | 6,620 | $ | 6,347 | ||||||||
Operating expenses |
(1,876 | ) | (1,874 | ) | (5,555 | ) | (5,467 | ) | ||||||||
Operating income |
360 | 368 | 1,065 | 880 | ||||||||||||
Other income |
30 | 25 | 57 | 48 | ||||||||||||
Other expense |
(1 | ) | (1 | ) | (1 | ) | (1 | ) | ||||||||
Unrealized gain on derivative contracts, net |
98 | 75 | 129 | 110 | ||||||||||||
Interest expense, net |
(293 | ) | (305 | ) | (879 | ) | (914 | ) | ||||||||
Net income |
$ | 194 | $ | 162 | $ | 371 | $ | 123 | ||||||||
Sales (millions of kWh) |
41,245 | 41,101 | 124,520 | 124,161 | ||||||||||||
Heating degree days (normal 246 and 3,440, respectively) |
264 | 139 | 3,123 | 3,101 | ||||||||||||
Cooling degree days (normal 546 and 614, respectively) |
735 | 669 | 861 | 808 | ||||||||||||
Combined degree days (normal 792 and 4,054, respectively) |
999 | 808 | 3,984 | 3,909 | ||||||||||||
Note: |
TVA uses weather degree days to measure the impact of weather on TVAs power operations. TVA calculates weather degree days for each of the five largest cities in TVAs service area. If the average temperature for a given day in one of these cities exceeds 65 degrees Fahrenheit, that city will have cooling degree days for that day equal to the amount by which the average temperature for that day exceeds 65 degrees Fahrenheit. Similarly, if the average temperature for a given day in one of these cities is lower than 65 degrees Fahrenheit, that city will have heating degree days for that day equal to the amount by which 65 degrees Fahrenheit exceeds the average temperature for that day. |
Net income for the three months ended June 30, 2007, was $194 million compared to net
income of $162 million for the same period in 2006. Significant items contributing to the $32
million increase in net income for the three months ended June 30, 2007, as compared to the three
months ended June 30, 2006, included a $23 million increase in unrealized gain on derivative
contracts, net, a $12 million decrease in net interest expense, and a $5 million increase in other
income. These items were partially offset by a $6 million decrease in operating revenues and a $2
million increase in operating expenses.
Net income for the nine months ended June 30, 2007, was $371 million compared to net income of
$123 million for the same period in 2006. Significant items contributing to the $248 million
increase in net income for the nine months ended June 30, 2007, as compared to the nine months
ended June 30, 2006, included a $273 million increase in operating revenues, a $35 million decrease
in net interest expense, a $19 million increase in unrealized gain on derivative contracts, net,
and a $9 million increase in other income. These items were partially offset by an $88 million
increase in operating expenses.
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Operating Revenues. Below is a detailed table of operating revenues for the three and nine
months ended June 30, 2007, and 2006.
Operating Revenues
Three Months Ended | Nine Months Ended | |||||||||||||||||||||||
June 30 | June 30 | |||||||||||||||||||||||
Percent | Percent | |||||||||||||||||||||||
2007 | 2006 | Change | 2007 | 2006 | Change | |||||||||||||||||||
Sales of Electricity |
||||||||||||||||||||||||
Municipalities and cooperatives |
$ | 1,863 | $ | 1,898 | (1.8 | %) | $ | 5,527 | $ | 5,406 | 2.2 | % | ||||||||||||
Industries directly served |
304 | 275 | 10.5 | % | 907 | 750 | 20.9 | % | ||||||||||||||||
Federal agencies and other |
29 | 27 | 7.4 | % | 80 | 85 | (5.9 | %) | ||||||||||||||||
Other revenue |
40 | 42 | (4.8 | )% | 106 | 106 | 0.0 | % | ||||||||||||||||
Total operating revenues |
$ | 2,236 | $ | 2,242 | (0.3 | )% | $ | 6,620 | $ | 6,347 | 4.3 | % | ||||||||||||
Significant items contributing to the $6 million decrease in operating revenues for the
three months ended June 30, 2007, as compared to the three months ended June 30, 2006, included:
| A $35 million decrease in revenues from municipalities and cooperatives attributable to a decrease in average rates of 2.1 percent partially offset by increased sales of 1.2 percent; | ||
| A $2 million decrease in revenues from other revenue largely attributable to decreased transmission revenues from wheeling activity; and | ||
| A $1 million decrease in revenues from federal agencies directly served (included in Federal Agencies and Other) due to a decrease in average rates of 5.1 percent partially offset by increased sales of 3.0 percent. |
Average rates decreased primarily due to the 4.5 percent decrease in firm wholesale electric
rates effective October 1, 2006.
These items were partially offset by:
| A $29 million increase in revenues from industries directly served attributable to an increase in average rates of 15.4 percent partially offset by decreased sales of 3.9 percent; and | ||
| A $3 million increase in revenues from off-system sales (included in Federal Agencies and Other) due to increased sales of 159.4 percent partially offset by a decrease in average rates of 0.4 percent. |
Significant items contributing to the $273 million increase in operating revenues for the nine
months ended June 30, 2007, as compared to the nine months ended June 30, 2006, included:
| A $121 million increase in revenues from municipalities and cooperatives due to increased sales of 0.5 percent and an increase in average rates of 2.6 percent; | ||
| A $157 million increase in revenues from industries directly served attributable to an increase in average rates of 21.9 percent partially offset by decreased sales of 0.4 percent; and | ||
| A $1 million increase in revenues from off-system sales due to increased sales of 23.7 percent partially offset by a decrease in average rates of 17.5 percent. |
Average rates increased mainly due to the 10.0 percent increase in firm wholesale electric
rates effective April 1, 2006, partially offset by the 4.5 percent decrease in firm wholesale
electric rates effective October 1, 2006.
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These items were partially offset by a $6 million decrease in revenues from federal agencies
directly served (included in Federal Agencies and Other) reflecting a decrease in average
rates of 3.0 percent and decreased sales of 4.5 percent.
A detailed table of electricity sales for the three and nine months ended June 30, 2007, and
2006 is below.
Electricity Sales
(Millions of kWh)
(Millions of kWh)
Three Months Ended | Nine Months Ended | |||||||||||||||||||||||
June 30 | June 30 | |||||||||||||||||||||||
Percent | Percent | |||||||||||||||||||||||
2007 | 2006 | Change | 2007 | 2006 | Change | |||||||||||||||||||
Sales of electricity |
||||||||||||||||||||||||
Municipalities and cooperatives |
33,352 | 32,962 | 1.2% | 99,361 | 98,894 | 0.5% | ||||||||||||||||||
Industries directly served |
7,384 | 7,683 | (3.9% | ) | 23,667 | 23,761 | (0.4% | ) | ||||||||||||||||
Federal agencies and other |
509 | 456 | 11.6% | 1,492 | 1,506 | (0.9% | ) | |||||||||||||||||
Total sales of electricity |
41,245 | 41,101 | 0.4% | 124,520 | 124,161 | 0.3% | ||||||||||||||||||
Significant items contributing to the 144 million kilowatt-hour increase in electricity
sales for the three months ended June 30, 2007, as compared to the three months ended June 30,
2006, included:
| A 390 million kilowatt-hour increase in sales to municipalities and cooperatives. The primary reason for the increase in sales was an increase of combined degree days of 191 days, or 23.6 percent. Sales to municipalities and cooperatives react more to weather than other categories of sales because residential power demand is more weather sensitive. During the three months ended June 30, 2007, there were 125, or 89.9 percent, more heating degree days and 66, or 9.9 percent, more cooling degree days than during the three months ended June 30, 2006; | ||
| A 40 million kilowatt-hour increase in off-system sales (included in Federal Agencies and Other) due to increased generation available for sale; and | ||
| A 13 million kilowatt-hour increase in sales to federal agencies directly served (included in Federal Agencies and Other) primarily as a result of increased testing hours at a large directly served federal agency. |
These items were partially offset by a 299 million kilowatt-hour decrease in sales to
industries directly served mainly attributable to a decrease in demand from a large directly served
industrial customer after a product line was shut down in April of 2007 due to storm damage.
Significant items contributing to the 359 million kilowatt-hour increase in electricity sales
for the nine months ended June 30, 2007, as compared to the nine months ended June 30, 2006,
included:
| A 467 million kilowatt-hour increase in sales to municipalities and cooperatives due to an increase in combined weather degree days of 75, or 1.9 percent. During the nine months ended June 30, 2007, there were 22, or 0.7 percent, more heating degree days and 53, or 6.6 percent, more cooling degree days than during the nine months ended June 30, 2006; and | ||
| A 45 million kilowatt-hour increase in off-system sales (included in Federal Agencies and Other) due to increased generation available for sale. |
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These items were partially offset by:
| A 94 million kilowatt-hour decrease in sales to industries directly served mainly attributable to a decrease in demand from a few large directly served industrial customers due to more unplanned outages at those facilities compared to the prior period, partially offset by an increase in demand to TVAs largest directly served industrial customer to accommodate higher production levels at its facility; and | ||
| A 59 million kilowatt-hour decrease in sales to federal agencies directly served (included in Federal Agencies and Other) primarily as a result of a decrease in demand by one of TVAs largest directly served federal agencies due to a change in the nature and scope of its test programs. |
Operating Expenses. Below is a detailed table of operating expenses for the three and nine
months ended June 30, 2007, and 2006.
Operating Expenses
Three Months Ended | Nine Months Ended | |||||||||||||||||||||||
June 30 | June 30 | |||||||||||||||||||||||
Percent | Percent | |||||||||||||||||||||||
2007 | 2006 | Change | 2007 | 2006 | Change | |||||||||||||||||||
Operating expenses |
||||||||||||||||||||||||
Fuel and purchased power |
$ | 779 | $ | 833 | (6.5% | ) | $ | 2,342 | $ | 2,295 | 2.0% | |||||||||||||
Operating and maintenance |
621 | 585 | 6.2% | 1,782 | 1,752 | 1.7% | ||||||||||||||||||
Depreciation, amortization, and accretion |
366 | 363 | 0.8% | 1,104 | 1,140 | (3.2% | ) | |||||||||||||||||
Tax equivalents |
110 | 93 | 18.3% | 327 | 280 | 16.8% | ||||||||||||||||||
Total operating expenses |
$ | 1,876 | $ | 1,874 | 0.1% | $ | 5,555 | $ | 5,467 | 1.6% | ||||||||||||||
Significant drivers contributing to the $2 million increase in operating expenses for the
three months ended June 30, 2007, as compared to the three months ended June 30, 2006, included:
| A $36 million increase in Operating and Maintenance expense. |
o | This increase was mainly a result of: |
| Increased outage and routine Operating and Maintenance costs at fossil fuel-fired plants of $29 million due to more outages during the third quarter of 2007 than the third quarter of 2006 and the significant planned recovery work on the three Paradise coal-fired units; | ||
| The Browns Ferry Nuclear Unit 1 precommercial operation of $23 million in the third quarter of 2007; and | ||
| A FCA net deferral and amortization for Operating and Maintenance expense of $2 million. In accordance with the FCA methodology, TVA has deferred the amount of Operating and Maintenance costs that were lower than the amount included in power rates for the third quarter of 2007. This $2 million deferred amount will be refunded to customers in future FCA adjustments. |
o | These items were partially offset by decreased pension financing costs of $22 million attributable to a 0.52 percent higher discount rate and a 0.50 percent higher than expected long-term rate of return on pension plan assets. |
| A $17 million increase in Tax Equivalents payments reflecting increased gross revenues from the sale of power during 2006 as compared to 2005. |
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| A $3 million increase in Depreciation, Amortization, and Accretion expense. |
o | This increase was primarily a result of a $5 million increase in accretion expense mainly reflecting the adoption of Financial Accounting Standards Board (FASB) Interpretation (FIN) No. 47 and the updated incremental accretion for Statement of Financial Accounting Standards (SFAS) No. 143. | ||
o | This item was partially offset by a $2 million decrease in depreciation expense primarily attributable to the depreciation rate reduction for Browns Ferry Nuclear Plant reflecting the 20-year license extension approved on May 4, 2006. |
The increases in Operating and Maintenance expense, Tax Equivalents
payments, and Depreciation, Amortization, and Accretion expense were partially offset by:
| A $54 million decrease in Fuel and purchased power expense. |
o | This decrease was primarily due to a $108 million decrease in purchased power expense. |
| The decrease in purchased power expense primarily reflected a FCA net deferral and amortization for purchased power expense of $144 million. In accordance with the FCA methodology, TVA has deferred the amount of purchased power costs that were higher than the amount included in power rates for the third quarter of 2007. This $144 million deferred amount will be charged to customers in future FCA adjustments. | ||
| This item was partially offset by: |
| Higher volume acquired of 0.2 percent which includes $26 million in purchased power related to the extended outage of Unit 3 at TVAs Paradise Fossil Plant; and | ||
| An increase in the average purchase price of 13.5 percent. |
o | The decrease in purchased power expense was partially offset by a $54 million increase in fuel expense. |
| The increase in fuel expense resulted primarily from: |
| Increased nuclear generation of 18.0 percent due to the restart of Browns Ferry Unit 1 in May 2007; and | ||
| A FCA net deferral and amortization for fuel expense of $69 million. In accordance with the FCA methodology, TVA has deferred the amount of fuel costs that were lower than the amount included in power rates for the third quarter of 2007. This $69 million deferred amount will be refunded to customers in future FCA adjustments. |
| These items were partially offset by lower aggregate fuel cost per kilowatt-hour net thermal generation of 5.6 percent. |
Significant drivers contributing to the $88 million increase in operating expenses for the
nine months ended June 30, 2007, as compared to the nine months ended June 30, 2006, included:
| A $47 million increase in Fuel and Purchased Power expense. |
o | This increase was mainly the result of a $90 million increase in fuel expense. |
| The increase in fuel expense primarily reflected: |
| Higher aggregate fuel cost per kilowatt-hour net thermal generation of 4.0 percent; | ||
| Increased coal-fired generation of 1.1 percent; and | ||
| A FCA net deferral and amortization for fuel expense of $36 million. In accordance with the FCA methodology, TVA has deferred the amount of fuel costs that were lower than the amount included in power rates for the first three quarters of 2007. This $36 million deferred amount will be refunded to customers in future FCA adjustments. |
o | The increase in fuel expense was partially offset by a $43 million decrease in purchased power expense. |
| The decrease in purchased power expense resulted primarily from: |
| A decrease in the average purchase price of 5.4 percent; and | ||
| A FCA net deferral and amortization for purchased power expense of $151 million. In accordance with the FCA methodology, TVA has deferred the amount of purchased power costs that were higher than the amount included in power rates for the first three quarters |
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of 2007. This $151 million deferred amount will be charged to customers in future FCA adjustments. |
| These items were partially offset by a 22.3 percent increase in the volume of purchased power to accommodate for decreased total generation of 0.7 percent. This increase in volume includes $26 million of power purchased as a result of the extended outage of Unit 3 at TVAs Paradise Fossil Plant during the third quarter of 2007. |
| A $47 million increase in Tax Equivalents payments reflecting increased gross revenues from the sale of power during 2006 as compared to 2005. | ||
| A $30 million increase in Operating and Maintenance expense. |
o | This increase was mainly a result of: |
| Increased outage and routine Operating and Maintenance costs at fossil fuel-fired plants of $44 million due to more outages during the first nine months of 2007 and the significant planned recovery work on the three Paradise Fossil Plant coal-fired units; | ||
| The Browns Ferry Unit 1 pre-commercial operation of $23 million in 2007; | ||
| A $17 million write-down of a scrubber project at TVAs Colbert Fossil Plant (Colbert); | ||
| Write-downs of $6 million relating to other construction work in progress assets; and | ||
| A FCA net deferral and amortization for Operating and Maintenance expense of $6 million. In accordance with the FCA methodology, TVA has deferred the amount of Operating and Maintenance costs that were lower than the amount included in power rates for the first three quarters of 2007. This $6 million deferred amount will be refunded to customers in future FCA adjustments. |
o | These items were partially offset by decreased pension financing costs of $69 million as a result of a 0.52 percent higher discount rate and a 0.50 percent higher than expected long-term rate of return on pension plan assets. |
The increases in Fuel and Purchased Power expense, Tax Equivalents
payments, and Operating and Maintenance expense were partially offset by:
| A $36 million decrease in Depreciation, Amortization, and Accretion expense. |
o | This decrease was mainly a result of a $47 million decrease in depreciation expense primarily attributable to the depreciation rate reduction for Browns Ferry Nuclear Plant reflecting the 20-year license extension approved on May 4, 2006. | ||
o | This item was partially offset by an $11 million increase in accretion expense mainly reflecting the adoption of FIN No. 47 and the updated incremental accretion of SFAS No. 143. |
Other Income. Other Income increased $5 million from $25 million for the three
months ended June 30, 2006, to $30 million for the three months ended June 30, 2007, primarily due
to differences related to the timing of recognition of maintenance and testing services revenues.
Other Income also increased due to increased interest earnings on the collateral deposit
funds held by TVA, partially offset by a decrease in interest income from short-term investments.
See Note 1 Restricted Cash and Investments.
Other Income increased $9 million from $48 million for the nine months ended June 30,
2006, to $57 million for the nine months ended June 30, 2007, primarily due to differences related
to the timing of recognition of maintenance and testing services revenues. Other Income
also increased due to increased interest earnings on the collateral deposit funds held by TVA,
partially offset by a decrease in interest income from short-term investments. See Note 1
Restricted Cash and Investments.
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Unrealized Gain on Derivative Contracts, Net. Significant items contributing to the $23
million increase in net unrealized gain on derivative contracts for the three months ended June 30,
2007, as compared to the three months ended June 30, 2006, included:
| A $14 million larger gain related to the mark-to-market valuation of swaption contracts, from a $41 million gain in the third quarter of 2006 to a $55 million gain in the third quarter of 2007; and | ||
| A $9 million larger gain related to the mark-to-market valuation adjustment of an interest rate swap contract, from a $36 million gain in the third quarter of 2006 to a $45 million gain in the third quarter of 2007. |
A significant item contributing to the $19 million increase in net unrealized gain on
derivative contracts for the nine months ended June 30, 2007, as compared to the same period in
2006 was a $58 million smaller loss related to the mark-to-market valuation adjustment of an
embedded call option, from a $60 million loss in the nine months ended June 30, 2006, to a $2
million loss in the nine months ended June 30, 2007.
This item was partially offset by:
| A $24 million smaller gain related to the mark-to-market valuation adjustment of an interest rate swap contract, from a $79 million gain in the nine months ended June 30, 2006, to a $55 million gain in the nine months ended June 30, 2007; and | ||
| A $15 million smaller gain related to the mark-to-market valuation of swaption contracts, from a $92 million gain in the nine months ended June 30, 2006, to a $77 million gain in the nine months ended June 30, 2007. |
Interest Expense. A detailed table of interest expense and interest rates for the three and
nine months ended June 30, 2007, and 2006, is below.
Interest Expense
Three Months Ended | Nine Months Ended | |||||||||||||||||||||||
June 30 | June 30 | |||||||||||||||||||||||
Percent | Percent | |||||||||||||||||||||||
2007 | 2006 | Change | 2007 | 2006 | Change | |||||||||||||||||||
Interest expense |
||||||||||||||||||||||||
Interest on debt |
$ | 334 | $ | 342 | (2.3% | ) | $ | 1,009 | $ | 1,016 | (0.7% | ) | ||||||||||||
Amortization of debt discount, issue,
and reacquisition costs, net |
4 | 5 | (20.0% | ) | 14 | 15 | (6.7% | ) | ||||||||||||||||
AFUDC and nuclear fuel
expenditures |
(45 | ) | (42 | ) | 7.1% | (144 | ) | (117 | ) | 23.1% | ||||||||||||||
Net interest expense |
$ | 293 | $ | 305 | (3.9% | ) | $ | 879 | $ | 914 | (3.8% | ) | ||||||||||||
Percent | Percent | |||||||||||||||||||||||
2007 | 2006 | Change | 2007 | 2006 | Change | |||||||||||||||||||
Interest rates (average) |
||||||||||||||||||||||||
Long-term |
5.98 | 6.17 | (3.1 | %) | 5.98 | 5.99 | (0.2 | %) | ||||||||||||||||
Discount notes |
5.22 | 4.82 | 8.3 | % | 5.21 | 4.29 | 21.4 | % | ||||||||||||||||
Blended |
5.89 | 6.08 | (3.1 | %) | 5.90 | 5.83 | 1.2 | % |
Significant items contributing to the $12 million decrease in net interest expense for the
three months ended June 30, 2007, as compared to the three months ended June 30, 2006, included:
| A decrease in the average long-term interest rate from 6.17 percent to 5.98 percent; | ||
| A decrease of $983 million in the average balance of long-term debt outstanding; and | ||
| A $3 million increase in AFUDC due to a 9.4 percent increase in the construction work in progress base. |
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These items were partially offset by: |
| An increase in the average discount notes interest rate from 4.82 percent to 5.22 percent; and | ||
| An increase of $998 million in the average balance of discount notes outstanding. |
Significant items contributing to the $35 million decrease in net interest expense for the
nine months ended June 30, 2007, as compared to the nine months ended June 30, 2006, included:
| A decrease in the average long-term interest rate from 5.99 percent to 5.98 percent; | ||
| A decrease of $804 million in the average balance of long-term debt outstanding; and | ||
| A $27 million increase in AFUDC due to a 20.1 percent increase in the construction work in progress base. |
These items were partially offset by:
| An increase in the average discount notes interest rate from 4.29 percent to 5.21 percent; and | ||
| An increase of $267 million in the average balance of discount notes outstanding. |
Off-Balance Sheet Arrangements
TVA has entered into one transaction that might 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 has a committed
capacity of 440 megawatts, and the term of the agreement is 30 years. Under the accounting guidance
provided by FIN No. 46, Consolidation of Variable Interest Entities, as revised by FIN No. 46R
(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
Partnerships balance sheet, results of operations, and cash flows for the year ended September 30,
2006. Power purchases for the three and nine months ended June 30, 2007, under the agreement
amounted to $33 million and $93 million, respectively, and the remaining financial commitment under
this agreement is $4.5 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
(GAAP), 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
regards to the level of judgment involved and its potential impact on TVAs 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 TVAs financial condition, changes in financial position, or results
of operations. TVAs critical accounting policies are discussed in Item 7, Managements Discussion
and Analysis of Financial Condition and Results of Operations Critical Accounting Policies and
Estimates and Note 1 Summary of Significant Accounting Policies in the Annual Report.
TVAs power rates are not subject to regulation through a public service commission or other
similar entity. The TVA 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) TVAs 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 TVAs 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 GAAP for non-regulated entities. Regulatory
assets generally represent incurred costs that have been deferred because such costs are probable
of future recovery in customer rates. Regulatory liabilities generally represent obligations to
make refunds to customers for previous collections for costs that are not likely to be incurred.
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Management assesses whether the regulatory assets are probable of future recovery by considering
factors such as applicable regulatory changes, potential legislation, and changes in technology.
Based on this assessment, management believes the existing regulatory assets are probable of
recovery. This determination reflects the current regulatory and political environment and is
subject to change in the future. If future recovery of regulatory assets ceases to be probable, TVA
could be required to write-off the cost of these assets under the provisions of SFAS No. 101,
Regulated EnterprisesAccounting 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
regulatory accounting under SFAS No. 71 ceased to apply.
New Accounting Standards and Interpretations
Accounting Changes and Error Corrections. In May 2005, the FASB issued SFAS No. 154,
Accounting Changes and Error Corrections a replacement of APB Opinion No. 20 and FASB Statement
No. 3, which replaces Accounting Principles Board (APB) Opinion No. 20, Accounting Changes,
and SFAS No. 3, Reporting Accounting Changes in Interim Financial Statements. This statement
applies to all voluntary changes in accounting principles and also applies to changes required by
an accounting pronouncement in the unusual instance that the pronouncement does not include
specific transition provisions. This statement requires, unless impracticable, retrospective
application to prior periods financial statements of changes in accounting principles. If it is
impracticable to determine the period-specific effects of an accounting change on one or more
individual prior periods presented, this statement requires that the new accounting principle be
applied to the balances of assets and liabilities as of the beginning of the earliest period for
which retrospective application is practicable and that a corresponding adjustment be made to the
opening balance of retained earnings for that period rather than being reported in an income
statement. When it is impracticable to determine the cumulative effect of applying a change in
accounting principle to all prior periods, this statement requires that the new accounting
principle be applied as if it were adopted prospectively from the earliest date practicable. This
statement also requires that a change in depreciation, amortization, or depletion method for
long-lived, nonfinancial assets be accounted for as a change in accounting estimate effected by a
change in accounting principle. This statement became effective for TVA beginning in 2007.
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, 2007, and interim periods within
those fiscal years. At this time, TVA is evaluating the requirements of this statement and has not
yet determined the impact of its implementation, which may or may not be material to TVAs results
of operations or financial position.
Accounting for Defined Benefit Pension and Other Postretirement Plans. On September
29, 2006, FASB issued 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
will require employers to fully recognize the obligations associated with single-employer defined
benefit pension, retiree healthcare, and other postretirement plans in their financial statements.
Specifically, the new standard requires an employer to recognize in its statement of financial
position an asset for a plans overfunded status or a liability for a plans underfunded status;
measure a plans assets and its obligations that determine its funded status as of the end of the
employers 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. Those changes will be
reported in comprehensive income of a business entity and in changes in net assets of a
not-for-profit organization.
The requirement to recognize the funded status of a benefit plan and the disclosure
requirements are effective for TVA as of the end of the fiscal year ending after June 15, 2007.
TVA plans to apply the new standard for its 2007 year-end financial statements and recognize on its
September 30, 2007 Balance Sheet the funded status of its pension and other postretirement benefit
plans. However, had TVA been required to adopt the standard as of its last actuarial valuation date
(September 30, 2006), TVA would have recorded the following amounts on its Balance Sheet for the
year then ended: a regulatory asset of $795 million, additional pension and postretirement
obligations of $368 million and $152 million, respectively, and the reclassification to regulatory
assets of an intangible asset with a balance of $275 million, representing unamortized prior
service cost. The net effect of recognizing such amounts would have been to increase total assets
and liabilities by $520 million at that date.
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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 entitys 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 statement and has not yet determined the
potential impact of its implementation, which may or may not be material to TVAs 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, and 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 TVAs financial position.
Accounting for Misstatements. On September 13, 2006, the Securities and Exchange
Commission issued Staff Accounting Bulletin No. 108, Considering the Effects of Prior Year
Misstatements when Quantifying Misstatements in Current Year Financial Statements. This bulletin
provides interpretive guidance on how the effects of the carryover or reversal of prior year
misstatements should be considered in quantifying a current year misstatement. Application of the
guidance will become effective for TVA with its annual report for the year ending September 30,
2007. TVA is not aware of any potential misstatements at this time.
Legislative
TVA was created by the TVA Act, and legislation is introduced from time to time that if
enacted would directly or indirectly affect TVAs operations. See Item 7, Managements Discussion
and Analysis of Financial Condition and Results of Operations Legislative and Regulatory Matters
in the Annual Report for a discussion of legislative initiatives that may affect TVA.
Presidents Budget
On February 5, 2007, the Office of Management and Budget (OMB) transmitted the Presidents
proposed 2008 federal budget to Congress. In the portions specifically relating to TVA, the
proposed budget recommends:
| Expanding the types of financial arrangements that count toward TVAs $30 billion debt ceiling; | ||
| Requiring TVA to register its debt securities with the Securities and Exchange Commission; and | ||
| Allowing Congress to establish the amount of TVAs Office of Inspector Generals budget and directing TVA to fund the amount with power revenues beginning in 2008. Funding for TVAs Office of the Inspector General is currently paid directly by TVA. |
The first recommendation has been included in a draft bill prepared by OMB, but it has not yet
been introduced in Congress. The other recommendations have not been introduced in any legislation
or included in any draft bill.
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Proposed Legislation
On March 13, 2007, Senators Jim Bunning and Mitch McConnell, both Republicans from Kentucky,
introduced the Access to Competitive Power Act of 2007 (the Bill) in the Senate. The Bill would
provide as follows:
FERC Jurisdiction TVA and federal power marketing agencies would be subject to greater FERC jurisdiction with respect to transmission, including rates, terms, and conditions of service. | ||
Anti-Cherrypicking Provision 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. (With the exception of wheeling power to Bristol, Virginia, the anti-cherrypicking provision precludes TVA from being ordered to wheel another suppliers power to a customer if the power would be consumed within TVAs defined service territory.) | ||
Stranded Costs If TVA provides transmission service to any distributor pursuant to a FERC wheeling order, TVA may not recover any stranded cost from that distributor. | ||
Noticing Distributors Distributors that have given termination notices to TVA on or before December 31, 2006, would have express authority under federal law to: |
(1) | Construct, own, and operate any generation facility, individually or jointly with other distributors; | ||
(2) | Receive partial requirements services from TVA; | ||
(3) | Receive transmission services from TVA that are sufficient to meet all electric energy requirements of the distributors; and | ||
(4) | Elect, not later than 180 days after enactment, to rescind the termination notice without the imposition of a reintegration fee or any similar fee. |
Non-Noticing Distributors Distributors that have not given termination notices to TVA on or before December 31, 2006, would have express authority under federal law to: |
(1) | Construct, own, and operate any generation facility, individually or jointly with another distributor; and | ||
(2) | Receive partial requirements from TVA within a ratable limit, which cumulatively stays within a three percent compounded annual growth rate on the TVA system. |
SEPA Power Any distributor which 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. |
(1) | TVA would be required to provide transmission to enable such distributor to receive its share of SEPA power at one or more of the distributors delivery points specified by that distributor; and | ||
(2) | The price that such distributor would pay for its SEPA power would be the same rate that TVA pays for the SEPA power that it receives for the remaining distributors. |
Privatization Within 180 days of enactment, the Government Accountability Office (GAO) would be required to conduct a study of the costs, benefits, and other effects of privatizing TVA and report the results to Congress. | ||
TVA Debt Within 180 days of enactment, GAO would be required to conduct a study of the financial structure of, and the amount of debt held by, TVA. |
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Environmental
As is the case across the utility industry and in other sectors, TVAs activities are subject
to certain federal, state, and local environmental statutes and regulations. Major areas of
regulation affecting TVAs 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, Managements Discussion and
Analysis of Financial Condition and Results of Operations Environmental Matters in the Annual
Report.
TVA has incurred and continues to incur substantial capital and operating and maintenance
costs in order to comply with evolving environmental requirements. Many of these costs are
associated with the operation of TVAs 59 coal-fired generating units. While it is not possible to
predict with any precision how these evolving requirements will impact the operation of existing
and new coal-fired and other fossil-fuel generating units, it is virtually certain that
environmental requirements placed on the operation of these generating units will continue to
become more restrictive. Litigation over emissions from coal-fired generating units is also
occurring, including litigation against TVA. See Note 7.
Several existing regulatory programs have been and are being made more stringent in their
application to fossil-fuel units and additional regulatory programs affecting fossil-fuel units
were promulgated in 2005, including the Clean Air Interstate Rule (CAIR), which requires
significant utility reductions of emissions of sulfur dioxide and nitrogen oxides in the eastern
half of the United States (including all of TVAs operating areas), and the Clean Air Mercury Rule
(CAMR). TVA had previously estimated its total capital cost for reducing emissions from its power
plants from 1977 through 2010 to reach $5.8 billion, $4.6 billion of which had already been spent
as of September 30, 2006. TVA estimates that compliance with CAIR and CAMR could lead to additional
costs of $3.0 billion to $3.5 billion in the next decade if TVA should continue to operate all of
its present coal plants. TVA has taken and is taking significant voluntary steps to reduce the
carbon intensity of its generation, including the recovery of Browns Ferry Unit 1, power uprates of
Browns Ferry Units 2 and 3, and the hydroelectric modernization program. Moving forward, TVA
intends to make decisions that give strong consideration to fuel mix and generation assets that are
low- or zero-carbon emitting resources. There could be additional material costs if reductions of
carbon dioxide are mandated, or if future legislative, regulatory, or judicial actions lead to more
stringent emission reduction requirements, and while these costs cannot be accurately predicted at
this time, TVA has begun to incorporate the possibility of mandatory carbon reductions into its
long range planning. TVA continues to monitor these developments and will assess any potential
financial impacts as information becomes available.
On June 21, 2007, the Environmental Protection Agency (EPA) proposed lowering the 8-hour
ozone National Ambient Air Quality Standard. This proposal begins a process that will lead to a
final decision on revising the primary standard in March 2008. Meeting the more stringent EPA
standards for ozone (smog) contained in the proposal will challenge states and communities in the
Tennessee Valley and across the country. The current primary standard, set in 1997, is 0.08 parts
per million (ppm). EPA is proposing to lower the primary standard to between 0.075 ppm and 0.070
ppm, and is also proposing to add a new secondary ozone standard to address impacts on vegetation.
If EPA adopts the proposed standards, many urban areas and surrounding counties in the Tennessee
Valley and throughout the eastern United States are likely to exceed the new standards and be
designated as non-attainment areas. Non-attainment designations can have adverse economic
implications for areas that are so designated. Existing emission sources in non-attainment areas
can be required to install additional controls, and new sources planning to locate in such areas
are required to meet more stringent emission control requirements and obtain offsets for their
emissions from other sources in the non-attainment area. In addition, transportation projects such
as roadway expansions or repairs must demonstrate conformity with State plans to return the area to
attainment status or risk the loss of Federal highway funds. An increase in the number of counties
in the Tennessee Valley designated as non-attainment areas is also likely to focus additional
regulatory attention on all nitrogen oxide emission sources including TVA sources.
In February 2007, TVA announced plans to install additional emissions control equipment at the
John Sevier
Fossil Plant located near Rogersville, Tennessee. TVA has begun adding selective non-catalytic
reduction (SNCR) systems to reduce nitrogen oxide emissions and is designing scrubber technology
to reduce sulfur dioxide emissions from the four unit 712-megawatt plant. The first SNCR on Unit 1
began operation in May 2007, with similar equipment planned for installation on the other three
units by 2010. Construction of the planned scrubber is scheduled to begin in 2008 with completion
scheduled for 2012. TVA also installed and began operation of a second SNCR on Unit 4 at the
Johnsonville Fossil Plant in May 2007, and is continuing to operate the previously installed SNCR
on Johnsonville Unit 1.
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One of the results of the major reductions in atmospheric emissions resulting from the clean
air expenditures discussed above and in the Annual Report is that wastewaters at TVA fossil
facilities and across the utility industry may be changing because of waste streams from air
quality control technologies. Varying amounts of ammonia or similar compounds used as a necessary
component of selective catalytic reduction/SNCR operation may end up in facility wastewater ponds
that may discharge through outfalls permitted under the Clean Water Act (CWA). Operation of
scrubbers for sulfur dioxide control also results in additional amounts of pollutants introduced
into facility wastewater treatment ponds. EPA is currently collecting information to determine if
the Steam Electric Point Source Effluent Guidelines (Effluent Guidelines) under the Clean Water
Act need to be revised. If the Effluent Guidelines are revised, more restrictive discharge
limitations for existing parameters or the addition of new parameters could potentially result in
additional wastewater treatment expense to meet requirements of the CWA. These costs cannot be
accurately predicted at this time, and TVA is continuing to closely monitor EPAs data collection
activities and the progress of the Effluent Guidelines review process. On the state level, new
numeric nutrient criteria development and implementation (an EPA requirement) may require
additional treatment costs to reduce nitrogen concentrations being added to the waste treatment
ponds as a result of operation of air pollution control equipment. TVA is closely monitoring the
development and implementation of Tennessee Valley states numeric nutrient criteria.
As a part of the 2006 tri-ennial review of State Water Quality Standards in Tennessee, the
Tennessee
Department of Environment and Conservation (TDEC) lowered its threshold for issuing a
Precautionary Fish Consumption Advisory (Precautionary Advisory) due to mercury to 0.3 ppm
because of new research and based on EPAs new water quality criterion for methlymercury. The
previously used thresholds were 0.5 ppm for a Precautionary Advisory and 1.0 ppm for a Do Not
Consume Advisory. In Tennessee a Precautionary Advisory recommends that sensitive populations such
as children and women of child-bearing age should not consume the fish species named, and that all
other persons should limit consumption of the named species to one meal per month. A Do Not
Consume Advisory recommends that certain fish species should not be consumed by anyone in any
amount. As a result of lowering the threshold, Precautionary Advisories were issued for several
additional stream and reservoir segments within the State of Tennessee, including seven streams and
reservoir segments in the Tennessee Valley Watershed. TDECs announcement of additional
Precautionary Advisories for several Tennessee water bodies does not mean that mercury levels in
fish are increasing. TVA has been monitoring mercury levels in fish and sediments in TVA reservoirs
for the last 35 years, and TVAs data was provided to TDEC as a part of its review process. TVAs
data show significant reductions in mercury concentrations in fish from the reservoirs with known
industrial discharges that have now ceased operation. Other than those areas historically impacted
by industrial discharges, mercury concentrations in fish have tended to fluctuate through time with
no discernable trend in fish from most reservoirs. Despite greatly increased burning of coal for
electricity generation, current and historic data records indicate that mercury concentrations in
reservoir sediments have remained stable or declined.
In November 2006, TVA received a letter from the attorneys for one of the parties conducting
the removal action at the Ward Transformer Superfund Site in North Carolina that put TVA on notice
that it was identified as a Comprehensive Environmental Response, Compensation, and Liability Act
(CERCLA) liable party, and that one or more of the parties intends to pursue a contribution claim
against TVA. The Ward Transformer site was one of two non-TVA areas identified in TVAs Annual
Report for which TVA was unable to estimate its potential liability. At TVAs request, the
attorneys provided information showing that TVA sent additional equipment that had not been
previously identified by TVA, and in one or more transactions with Ward, transformers containing
polychlorinated biphenyls (PCBs) which were sent to the Ward Transformer site were either
repaired, rebuilt and sold, or scrapped. For a further discussion of the Ward Transformer
contamination claim, seeNotification of Potential Liability for Ward Transformer Site in Note 7 of
this Quarterly Report.
In addition to the on-site cleanup activities, off-site contamination has been discovered
which is believed to extend to the Neuse River and includes water bodies in a county and state
park. The State of North Carolina has issued fish consumption advisories due to PCBs in areas up to
20 miles downstream of the Ward Transformer site. The expansion of the area believed to have been
contaminated offsite and the potential for assessments of natural resource damages to liable
parties could substantially raise the cleanup costs. As yet there is no formal estimate of the
costs associated with cleanup or resource damages, nor has TVAs potential share of those costs
been determined.
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Legal
Legal Proceedings to Which TVA Is a Party
As discussed in Note 7, TVA is involved in a number of lawsuits and claims relating to a
variety of issues. In accordance with SFAS No. 5, Accounting for Contingencies, TVA had accrued
approximately $28 million as of June 30, 2007, related to pending litigation and other claims. If
actual liabilities significantly exceed this estimate, TVAs results of operations, liquidity, and
financial condition could be materially adversely affected. See Note 7.
Significant Litigation to Which TVA Is Not a Party
Clean Air Developments. On April 2, 2007, in Massachusetts v. EPA, a case concerning
whether EPA has the authority and duty to regulate carbon dioxide emissions under the CAA, the
Supreme Court found that greenhouse gases, including carbon dioxide, are pollutants under the CAA
and thus EPA does have the authority to regulate these gases. The Supreme Court also concluded
that EPAs refusal to regulate these pollutants was based on impermissible reasons, and remanded
the case to EPA to ground its reasons for action or inaction in the statute. While this case
focused on carbon dioxide emissions from motor vehicles, it sets a precedent for regulation in
other industrial sectors, such as the electric utility industry.
New Source Review. On April 2, 2007, the Supreme Court also 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 EPAs NSR enforcement case against Duke Energy. The New Source Review
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
under EPAs Prevention of Significant Deterioration 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.
TVA is currently involved in two NSR cases (one involving Bull Run and another at Colbert).
See Note 7 in this Quarterly Report for a discussion of these cases. The Supreme Courts rejection
of the hourly standard for emissions testing could undermine one of TVAs 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 Courts 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.
At this point, no estimate can be made regarding the impact of any such suits on TVA.
Clean Water Developments
In the second phase of a three-part rulemaking to minimize the adverse impacts from cooling
water intake structures on fish and shellfish, as required under Section 316(b) of the CWA, the EPA
promulgated a final rule for existing power producing facilities (the Phase II rule) that became
effective on September 7, 2004. The Phase II rule required existing facilities to select among
several different compliance options for reducing the number of organisms pinned against and/or
drawn into the cooling systems. These included development of a site-specific compliance option
based on application of cost-cost or cost-benefit tests. The site specific tests were designed to
ensure that a facilitys costs are not significantly greater than cost projections in the rule or
the benefits derived from taking mitigation actions. Actions taken to compensate for any impacts by
restoring habitat, or pursuing other options such as building hatcheries for fish/shellfish
production, would have counted towards compliance.
On January 25, 2007, the United States Court of Appeals for the Second Circuit (the Second
Circuit) issued a decision in a proceeding brought by environmental groups, industry groups, and
certain northeastern states challenging the EPAs Phase II rule. The Second Circuit held that costs
cannot be compared to benefits in picking the best technology available (BTA) to minimize the
adverse environmental impacts of intake structures. Instead, the court held that the EPA is allowed
to consider costs in two ways: (1) to determine what technology can reasonably be borne by
industry, and (2) to engage in cost-effectiveness analysis in determining BTA. Finding the
rulemaking record to be unclear on whether the EPA had relied on a cost-benefit analysis or a
cost-effectiveness analysis, the Second
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Circuit remanded the EPAs BTA determination, giving the EPA the option to provide a reasonable
explanation of its determination or make a new determination based on the permissible cost
considerations set out in the Second Circuit opinion. The Second Circuit also remanded provisions
of the EPA rule that allowed the use of a site-specific cost-benefit test and restoration measures
(such as building hatcheries) to demonstrate compliance, holding that these rule provisions were
based on an impermissible construction of the statute. Several other provisions of the Phase II
rule such as the one that sets the performance standards as a range rather than one national
standard were also remanded.
On July 5, 2007, the Second Circuit denied a petition filed by industry stakeholders for panel
and en banc rehearing. EPA has until October 3, 2007, to file a petition for certiorari with the
U.S. Supreme Court but it is unknown whether EPA will do so.
On July 9, 2007, EPA suspended all but one provision of the Phase II rule until the agency has
resolved the issues raised by the Second Circuits remand. The provision that was retained
requires permitting authorities to apply, in the interim, Best Professional Judgment (BPJ)
controls for existing facilities. BPJ controls are those that reflect the best technology
available for minimizing the adverse environmental impacts of intake structures. The use of BPJ
controls reflects a reversion to the regulatory process that was used by permitting authorities to
regulate the impact of intake structures prior to the promulgation of the Phase II rule.
All of the intakes at TVAs existing coal and nuclear generating facilities were subject to
the Phase II rule. TVA had been in the process of determining what was needed to comply with the
Phase II rule, and had believed that some expenditures might have been required. These earlier
assessments are now being re-evaluated in light of the Second Circuits decision, and EPAs
subsequent decision to suspend the Phase II rule and revert to BPJ controls. Given the uncertainty
over the ultimate outcome of the appellate process and what the changes in the final rule as
ultimately issued by EPA will be, TVA cannot assess the potential consequences at this time.
Management Changes
TVA Board Nominations
On July 11, 2007, President George W. Bush announced the nomination of three individuals to
serve on the TVA Board. Two of these individuals, Bishop William H. Graves of Memphis, Tennessee,
and Susan Richardson Williams of Knoxville, Tennessee, are currently TVA Directors and have been
nominated for new terms. The third individual is Thomas C. Gilliland of Blairsville, Georgia. Mr.
Gilliland, age 59, is executive vice president, secretary, general counsel, and director for United
Community Banks, Inc., a bank holding company with assets of approximately $8.0 billion. He has
been with that company since 1992. If confirmed by the Senate, Mr. Gillilands term would expire
in 2011, and the terms of Bishop Graves and Ms. Williams would expire in 2012. The confirmation
hearings have not yet been scheduled.
New Executive Vice President of Fossil Power Group Named
On June 11, 2007, TVA announced the appointment of Preston Swafford, who has more than 23
years of utility experience, to succeed Joseph Bynum, who is retiring as executive vice president
of TVAs Fossil Power Group. Mr. Swafford joined TVA in 2006 and has held key roles in TVAs
nuclear operations which included directing engineering and technical services, nuclear assurance
and licensing, emergency services, project management, outage and scheduling, business services,
process methods, nuclear security, and other areas.
Before joining TVA, Mr. Swafford was with Exelon for more than ten years, most recently as
senior vice president of Exelon Energy Delivery, responsible for all aspects of technical services.
He previously served as Exelons senior vice president of Energy Delivery Operations, directing
daily operations for the transmission and distribution system of Exelon subsidiaries PECO and
ComEd. Mr. Swafford also served as vice president of Exelon Power, overseeing 19 hydroelectric and
pumped-storage units and nine fossil sites. He holds a Bachelor of Science degree in chemistry from
Truman State University and a masters degree in nuclear engineering from the University of
Missouri. He is certified as a senior reactor operator.
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New Chief Ethics and Compliance Officer Named
On July 19, 2007, TVA announced that Peyton T. Hairston, Jr. had been named TVAs chief ethics
and compliance officer, effective immediately. As chief ethics and compliance officer, Mr.
Hairston will organize and oversee a unified, corporate approach to compliance with laws and
regulations applicable to TVA. Along with his new position, Mr. Hairston is the senior vice
president of Corporate Responsibility and Diversity and TVAs external ombudsman.
New Chief Financial Officer and Executive Vice President of Financial Services Named
On August 3, 2007, TVA announced the appointment of Kimberly (Kim) Scheibe Greene as chief
financial officer and executive vice president, financial services (CFO), effective September 1,
2007. She will succeed John M. Hoskins, who has served as interim CFO since November 2006. Mr.
Hoskins will continue as senior vice president and treasurer, the position he held until assuming
the role of interim CFO. Ms. Greene will be responsible for all TVA financial functions, including
treasury, accounting, risk management, financial planning, and investor relations. She will report
to TVA President and CEO Tom Kilgore.
Ms. Greene joins TVA from Southern Company Services, where she is senior vice president of
finance and treasurer. In her current role, she directs financial planning and analysis,
enterprise risk management, capital markets and leasing, treasury, and investor relations for
Southern Company Services. Ms. Greene joined Southern Company Services in 1991 as a mechanical
engineer and progressed through various areas of engineering, including fossil and hydroelectric,
combustion turbine, and nuclear design. In 1994, she moved to Southern Energy Inc., now Mirant.
While there, she was responsible for Mirants south region asset management and coordination of
transmission system loads with adjoining utilities, including TVA. In 2002, Ms. Greene moved to
Southern Company Generation and Energy Marketing as director of portfolio management responsible
for trading strategies and long-term resource plans. She was named treasurer of Southern Company
Services in 2003. Southern Company is based in Atlanta and is one of the nations largest
investor-owned utilities.
Ms. Greene earned a bachelors degree in engineering science and mechanics from the University
of Tennessee. She also earned a masters degree in biomedical engineering from the University of
Alabama at Birmingham and a masters in business administration from Samford University in
Birmingham.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
There are no material changes related to market risks from the market risks disclosed under
Item 7, Managements Discussion and Analysis of Financial Condition and Results of Operations
Risk Management Activities in the Annual Report.
ITEM 4. CONTROLS AND PROCEDURES
TVA maintains disclosure controls and procedures that are designed to ensure that information
required to be disclosed in reports it 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.
An 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 interim chief financial officer and the vice president and controller) of the effectiveness of
TVAs disclosure controls and procedures as of June 30, 2007. Based on that evaluation, the
president and chief executive officer and members of the Disclosure Control Committee (including
the interim chief financial officer and the vice president and controller) concluded that, as a
result of two material weaknesses identified (described below), TVAs disclosure controls and
procedures were not effective as of June 30, 2007. However, to assess the financial statement
impact of these internal control deficiencies, TVA performed additional analyses, interim
supplemental procedures, and monitoring activities subsequent to quarter end. As a result of these
supplemental procedures, the president and chief executive officer, the interim chief financial
officer, and the vice president and controller have determined that there is reasonable assurance
that the financial statements included in this Quarterly Report fairly present, in all material
respects, TVAs financial condition, results of operations, and cash flows as of, and for, the
periods presented.
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TVA management has identified a material weakness in internal controls related to TVAs end
use billing arrangements with wholesale power customers. Under these arrangements, TVA relies on
the distributor customers to calculate major components of their own power bills. In fiscal year
2006, TVA requested annual Statement on Auditing Standards (SAS) 70 Type II internal control
reports on 12 specific control objectives from distributor customers and their third party billing
processors. Based on the evaluation of these SAS 70 Type II reports, TVA determined that
distributor customers who represent a material amount of TVAs 2007 revenue either had qualified
opinions and/or internal control test results that negatively impact their ability to meet TVAs
control objectives. However, subsequent to quarter end TVA has also performed additional revenue
analysis by comparing various metrics from billing data for distributor customers with similar
characteristics and benchmarking those with control weaknesses against those with strong controls.
As a result of this analysis, TVA has determined that reported revenues are not materially
misstated.
TVA management has also identified a material weakness related to controls over the
completeness, accuracy, and authorization of TVAs property, plant, and equipment transactions and
balances; the calculation of AFUDC; and the review of construction work in progress accounts for
proper closure to completed plant. To remediate this control weakness, TVA has developed a new
process for project approval to include the determination of proper project cost classification and
has made changes in staffing for fixed asset accounting. TVA is also formalizing the accounting
review of account balances and transactions and improving the documentation of management review
and approval. Additional analysis has been performed to ensure that property, plant, and equipment
is not materially misstated.
During the most recent fiscal quarter, there were no changes in TVAs internal control over
financial reporting that materially affected, or are reasonably likely to materially affect, TVAs
internal control over financial reporting. TVA is continuing to take steps to address the
identified material weaknesses in internal controls as described in the preceding two paragraphs.
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.
TVAs 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.
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PART
II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
See Note 7 in this Quarterly Report for a discussion of legal proceedings affecting TVA.
ITEM 1A. RISK FACTORS
The discussion below supplements the disclosure contained in Item 1A, Risk Factors in the
Annual Report. The factors described in Item 1A, Risk Factors in the Annual Report, together with
the risk factors discussed below and the other information contained in the Quarterly Report, could
materially affect TVAs business, financial condition, and operating results and should be
carefully considered. Further, the risks described in this Quarterly Report and in the Annual
Report are not the only risks facing TVA. Additional risks and uncertainties not currently known
to TVA management or that TVA management currently deems to be immaterial also may materially
adversely affect TVAs business, financial condition, and operating results.
Events at non-TVA facilities which affect the supply of water to TVAs generation facilities
may interfere with TVAs ability to generate power.
TVAs fossil and nuclear generation facilities depend on water from the river systems upon
which they are located for cooling water and for water to convert into steam to drive turbines.
While TVA manages the Tennessee River and large portions of its tributary system in order to
provide much of this necessary water, entities such as the U.S. Army Corps of Engineers operate and
manage other bodies of water upon which some TVA facilities rely. Events at these non-TVA bodies
of water or their associated hydroelectric facilities may interfere with the flow of water and may
result in TVA having insufficient water to meet the needs of its plants. In such scenarios, TVA
may be required to reduce generation at its affected facilities to levels compatible with the
available supply of water. See Part I, Item 2, Managements Discussion and Analysis of Financial
Condition and Results of Operations Business Overview Service Reliability in this Quarterly
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
None.
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ITEM 6. EXHIBITS
Exhibit No. | Description | |
10.1 | Amendment dated as of May 11, 2007, to $1,250,000,000 Spring Maturity Credit
Agreement Dated as of May 17, 2006, Among TVA, Bank of America, N.A., as
Administrative Agent, Bank of America, N.A., as a Lender, and the Other
Lenders Party Thereto |
|
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 |
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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:
August 14, 2007
TENNESSEE VALLEY AUTHORITY (Registrant) |
||||
By: | /s/ Tom D. Kilgore | |||
Tom D. Kilgore | ||||
President and Chief Executive Officer (Principal Executive Officer) |
||||
By: | /s/ John M. Hoskins | |||
John M. Hoskins | ||||
Interim Chief Financial Officer and Executive Vice President, Financial Services (Principal Financial Officer) |
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EXHIBIT INDEX
Exhibit No. | Description | |
10.1 | Amendment dated as of May 11, 2007, to $1,250,000,000 Spring Maturity Credit
Agreement Dated as of May 17, 2006, Among TVA, Bank of America, N.A., as
Administrative Agent, Bank of America, N.A., as a Lender, and the Other
Lenders Party Thereto |
|
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 |
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