Back to GetFilings.com



SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

____________

FORM 10-Q
____________


(Mark one)

X    QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2003

or

____ 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 1-8489

DOMINION RESOURCES, INC.
(Exact name of registrant as specified in its charter)

 

VIRGINIA
(State or other jurisdiction of incorporation or organization)

54-1229715
(I.R.S. Employer Identification No.)

 

 

120 Tredegar Street
RICHMOND, VIRGINIA
(Address of principal executive offices)


23219
(Zip Code)

 

 

(804) 819-2000
(Registrant's telephone number)

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    X   No         

Indicate by check mark whether the registrant is an accelerated filer (as defined by Rule 12b-2 of the Exchange Act). Yes   X   No       

At October 31, 2003, the latest practicable date for determination, 324,414,444 shares of common stock, without par value, of the registrant were outstanding.

PAGE 2

DOMINION RESOURCES, INC.

INDEX

 

 

Page  
Number

PART I. FINANCIAL INFORMATION


Item 1.


Consolidated Financial Statements

 

 


Consolidated Statements of Income - Three and Nine Months Ended September 30, 2003 and 2002


3

 


Consolidated Balance Sheets - September 30, 2003 and December 31, 2002


4

 


Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2003 and 2002


6

 


Notes to Consolidated Financial Statements


7


Item 2.


Management's Discussion and Analysis of Financial Condition and Results of Operations


22


Item 3.


Quantitative and Qualitative Disclosures About Market Risk


42


Item 4.


Controls and Procedures


44

 


PART II. OTHER INFORMATION

 


Item 1.


Legal Proceedings


45


Item 6.


Exhibits and Reports on Form 8-K


45

 

PAGE 3

DOMINION RESOURCES, INC.

PART I. FINANCIAL INFORMATION
ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)

 

Three Months Ended
September 30,

Nine Months Ended
September 30,

 

2003

2002

2003 

2002

(millions, except per share amounts)

Operating Revenue

$2,857

$2,545

$9,077

$7,512

 

 

 

 

 

Operating Expenses

 

 

 

 

Electric fuel and energy purchases, net

447 

418

1,224 

1,077

Purchased electric capacity

152 

173

463 

517

Purchased gas, net

323 

109

1,509 

734

Liquids, pipeline capacity and other purchases

111 

43

318 

123

Other operations and maintenance

721 

557

2,016 

1,636

Impairment - telecommunications assets

527 

--

544 

--

Depreciation, depletion and amortization

320 

312

936 

949

Other taxes

   106 

     97

   374 

   305

     Total operating expenses

2,707 

1,709

7,384 

5,341

 

 

 

 

 

Income from operations

   150 

   836

1,693 

2,171

 

 

 

 

 

Other income (expense)

     51 

     39

   (51)

     91

 

 

 

 

 

Interest and related charges:

 

 

 

 

  Interest expense - mandatorily redeemable trust
    preferred securities


28 


- --


28 


- --

  Interest expense - other

179 

204

601 

625

  Subsidiary preferred dividends and distributions of
    subsidiary trusts


       4 


     30


     67 


     88

     Total interest and related charges

   211 

   234

   696 

   713

 

 

 

 

 

Income (loss) before income taxes and minority interests

(10)

641

946 

1,549

 

 

 

 

 

Income taxes

251 

211

593 

525

Minority interests

      (5)

      --

    (26)

       --

Income (loss) before cumulative effect of changes in
    accounting principle


(256)


430


379 


1,024

Cumulative effect of changes in accounting principle
    (net of income taxes of $71)


      -- 


      --


   113 


       --

 

 

 

 

 

Net income (loss)

$(256)

$ 430

$492 

$1,024

 

 

 

 

 

Earnings Per Common Share - Basic

 

 

 

 

Income (loss) before cumulative effect of changes in
    accounting principle


$(0.79)


$1.55


$1.20 


$3.73

Cumulative effect of changes in accounting principle

       -- 

      --

  0.36 

     --

Net income (loss)

$(0.79)

$1.55

$1.56 

$3.73

 

 

 

 

 

Earnings Per Common Share - Diluted

 

 

 

 

Income (loss) before cumulative effect of changes in
    accounting principle


$(0.79)


$1.54


$1.20 


$3.71

Cumulative effect of changes in accounting principle

       -- 

      --

  0.36 

     --

Net income (loss)

$(0.79)

$1.54

$1.56 

$3.71

 

 

 

 

 

Dividends paid per common share

$0.645 

$0.645

$1.935 

$1.935

____________

The accompanying notes are an integral part of the Consolidated Financial Statements.

 

PAGE 4

DOMINION RESOURCES, INC.


CONSOLIDATED BALANCE SHEETS

(Unaudited)

ASSETS

September 30,
2003

December 31,
2002(1)

 

(millions)

Current Assets

 

 

Cash and cash equivalents

$  191 

$   291 

Customer accounts receivable (net of allowance of $60 and $63)

2,519 

2,568 

Other accounts receivable

748 

486 

Inventories

914 

637 

Derivative and energy trading assets

1,133 

1,365 

Margin deposit assets

85 

149 

Prepayments

138 

347 

Escrow account for debt refunding

-- 

500 

Other

     553 

     482 

     Total current assets

  6,281 

  6,825 

 

 

 

Investments

 

 

Available for sale securities

502 

564 

Nuclear decommissioning trust funds

1,756 

1,599 

Other

     923 

  1,011 

     Total investments

  3,181 

  3,174 

 

 

 

Property, Plant and Equipment, Net

 

 

Property, plant and equipment

35,744 

32,631 

Accumulated depreciation, depletion and amortization

(11,693)

(12,374)

     Total property, plant and equipment, net

  24,051 

  20,257 

 

 

 

Deferred Charges and Other Assets

 

 

Goodwill, net

4,328 

4,301 

Prepaid pension cost

1,916 

1,710 

Derivative and energy trading assets

441 

482 

Other

    1,338 

    1,160 

     Total deferred charges and other assets

    8,023 

    7,653 

     Total assets

$41,536 

$37,909 

____________

The accompanying notes are an integral part of the Consolidated Financial Statements.


(1)
The Consolidated Balance Sheet at December 31, 2002 has been derived from the audited Consolidated Financial Statements at that date.

PAGE 5

DOMINION RESOURCES, INC.


CONSOLIDATED BALANCE SHEETS

(Unaudited)


LIABILITIES AND SHAREHOLDERS' EQUITY

September 30,
2003

December 31,
2002(1)

 

(millions)

Current Liabilities

 

 

Securities due within one year

$  880 

$  2,125 

Short-term debt

875 

1,193 

Accounts payable, trade

2,304 

2,310 

Accrued interest, payroll and taxes

621 

606 

Derivative and energy trading liabilities

1,527 

1,609 

Other, net

      845 

       600 

     Total current liabilities

   7,052 

   8,443 

 

 

 

Long-Term Debt

 

 

Company obligated mandatorily redeemable
  preferred securities of subsidiary trusts(2)

1,397 

-- 

Other long-term debt

13,852 

11,968 

Notes payable - affiliates

           -- 

         92 

     Total long-term debt

 15,249 

 12,060 

 

 

 

Deferred Credits and Other Liabilities

 

 

Deferred income taxes and investment tax credits

4,658 

4,209 

Asset retirement obligations

1,596 

-- 

Derivative and energy trading liabilities

875 

690 

Other

      896 

       632 

     Total deferred credits and other liabilities

   8,025 

   5,531 

Total liabilities

 30,326 

 26,034 

 

 

 

Commitments and Contingencies (see Note 14)

 

 

 

 

 

Minority Interest

         10 

           8 

 

 

 

Company Obligated Mandatorily Redeemable
  Preferred Securities of Subsidiary Trusts
(2)


          --
 


    1,397
 

 

 

 

Subsidiary Preferred Stock Not Subject To
  Mandatory Redemption


       257
 


       257
 

 

 

 

Common Shareholders' Equity

 

 

Common stock - no par(3)

9,988 

9,051 

Other paid-in capital

60 

47 

Accumulated other comprehensive loss

(542)

(446)

Retained earnings

    1,437 

     1,561 

     Total common shareholders' equity

  10,943 

  10,213 

     Total liabilities and shareholders' equity

$41,536 

$37,909 

____________

(1) The Consolidated Balance Sheet at December 31, 2002 has been derived from the audited Consolidated Financial Statements at that date.

(2) Debt securities issued by Dominion Resources, Inc. and certain subsidiaries constitute 100 percent of the trusts' assets.

(3) Common stock information: 500 million shares authorized; 324 million shares and 308 million shares outstanding at September 30, 2003 and December 31, 2002, respectively.

PAGE 6

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

 

Nine Months Ended
September 30,

 

2003

2002

 

(millions)

Operating Activities

 

 

Net income

$492 

$ 1,024 

Adjustments to reconcile net income to cash from operating activities:

 

 

  Cumulative effect of changes in accounting principle, net of income taxes

(113)

--

  Net unrealized gains on energy-related derivatives held for trading purposes

(94)

(57)

Impairment of telecommunications assets

544 

--

  Depreciation, depletion and amortization

1,025 

1,043 

  Deferred income taxes and investment tax credits, net

402 

299 

  Changes in:

    Accounts receivable

54 

(353)

    Inventories

(278)

(104)

    Deferred fuel and purchased gas costs, net

(257)

(80)

    Prepayments

210 

226 

    Accounts payable

(11)

170 

    Accrued interest, payroll and taxes

43 

65 

    Margin deposit assets and liabilities

78 

(197)

    Other

      37 

 (131)

       Net cash provided by operating activities

 2,13

  1,905 

 

 

 

Investing Activities

 

 

Plant construction and other property additions

(1,526)

(901)

Additions to gas and oil properties, including acquisitions

(941)

(1,114)

Proceeds from sales of gas and oil properties

303 

-- 

Release of escrow deposit for debt refunding

500 

-- 

Purchase of Dominion Fiber Ventures senior notes

(633)

-- 

Acquisition of business

-- 

(402)

Other

   (178)

  (141)

      Net cash used in investing activities

(2,475)

(2,558)

 

 

 

Financing Activities

 

 

Issuance of common stock

936 

794 

Issuance of long-term debt

2,228 

1,709 

Repayment of long-term debt

(1,966)

(1,560)

Issuance of preferred securities of subsidiary trusts

-- 

400 

Repayment of preferred securities of subsidiary trusts

-- 

(135)

Redemption of subsidiary preferred stock

-- 

(175)

Repayment of short-term debt, net

(318)

(114)

Common dividend payments

(616)

(525)

Other

     (21)

     (44)

      Net cash provided by financing activities

    243 

     350 

 

 

 

     Decrease in cash and cash equivalents

(100)

(303)

     Cash and cash equivalents at beginning of period

    291 

     486 

     Cash and cash equivalents at end of period

  $191 

  $183 

 

 

 

Supplemental Cash Flow Information

 

 

Non-cash exchange of debt securities

  $500 

  $567 

____________

The accompanying notes are an integral part of the Consolidated Financial Statements.

PAGE 7

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


Note 1.     Nature of Operations


Dominion Resources, Inc. (Dominion) is a holding company headquartered in Richmond, Virginia. Its principal subsidiaries are Virginia Electric and Power Company (Virginia Power), Consolidated Natural Gas Company (CNG), and Dominion Energy, Inc. (DEI). Dominion and CNG are registered public utility holding companies under the Public Utility Holding Company Act of 1935 (1935 Act).


Virginia Power is a regulated public utility that generates, transmits and distributes electricity within a 30,000-square-mile area in Virginia and northeastern North Carolina. Virginia Power sells electricity to approximately 2.2 million retail customers, including governmental agencies, and to wholesale customers such as rural electric cooperatives, municipalities, power marketers and other utilities. Virginia Power has trading relationships beyond its retail service territory and buys and sells wholesale electricity, natural gas and other energy commodities.


CNG operates in all phases of the natural gas business, explores for and produces gas and oil and provides a variety of energy marketing services. Its regulated retail gas distribution subsidiaries serve 1.7 million residential, commercial and industrial gas sales and transportation customers in Ohio, Pennsylvania and West Virginia and its non-regulated retail gas, electric and products and services business serves 1.2 million residential and commercial customers in the Northeast and Midwest. Its interstate gas transmission pipeline system services each of its distribution subsidiaries, non-affiliated utilities and end-users in the Midwest, the Mid-Atlantic states and the Northeast. CNG's exploration and production operations are located in several major gas and oil producing basins in the lower 48 states, including the outer continental shelf and deep-water areas of the Gulf of Mexico. CNG's field services operations relate to Appalachian area natural gas supply and include storage and other services. CNG a lso operates a liquefied natural gas unloading and storage facility in Maryland.


DEI is involved in merchant generation, energy trading and marketing and natural gas and oil exploration and production in the United States and Canada.


Dominion manages its daily operations through three primary operating segments: Dominion Energy, Dominion Delivery and Dominion Exploration & Production. In addition, Dominion reports its corporate and other operations as a segment. Assets remain wholly owned by the legal subsidiaries.


The term "Dominion" is used throughout this report and, depending on the context of its use, may represent any of the following: the legal entity, Dominion Resources, Inc., one of Dominion Resources, Inc.'s consolidated subsidiaries or the entirety of Dominion Resources, Inc. and its consolidated subsidiaries.

Note 2.    Significant Accounting Policies


As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying unaudited Consolidated Financial Statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (generally accepted accounting principles). These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes for the year ended December 31, 2002 as well as the quarterly reports for previous interim periods of 2003 filed on Form 10-Q. On May 9, 2003, Dominion filed a current report on Form 8-K that included its Consolidated Financial Statements and Notes for the year ended December 31, 2002, which were reformatted to reflect the transfer of electric transmission operations to Dominion Energy from Dominion Delivery effective January 1, 2003. References to the Consolidated Financial Statements and Notes for the year ended December 31, 2002 refer to those included in the May 9, 2003 current report on Form 8-K.


In the opinion of management, the accompanying unaudited Consolidated Financial Statements contain all adjustments, including normal recurring accruals, necessary to present fairly Dominion's financial position as of September 30, 2003, its results of operations for the three and nine months and cash flows for the nine months ended September 30, 2003 and 2002.


The accompanying unaudited Consolidated Financial Statements represent Dominion's accounts after the elimination of intercompany transactions. Dominion follows the equity method of accounting for investments with less than or equal to a 50 percent interest in partnerships or corporate joint ventures when Dominion is able to exercise significant influence over the financial and operating policies of the investee. For all other investments, the cost method is applied.

PAGE 8

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


The accompanying unaudited Consolidated Financial Statements reflect certain estimates and assumptions made by management in accordance with generally accepted accounting principles. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the Consolidated Financial Statements and the reported amounts of revenues and expenses for the periods presented. Actual results may differ from those estimates.


Dominion reports certain contracts and instruments at fair value in accordance with generally accepted accounting principles. Market pricing and indicative price information from external sources are used to measure fair value when available. In the absence of this information, Dominion estimates fair value based on near-term and historical price information and statistical methods. For individual contracts, the use of differing assumptions could have a material effect on the contract's estimated fair value. See Note 2 to the Consolidated Financial Statements for the year ended December 31, 2002 for a more detailed discussion of Dominion's estimation techniques.


The results of operations for the interim periods are not necessarily indicative of the results expected for the full year. Information for quarterly periods is affected by seasonal variations in sales, rate changes, timing of recovery of electric fuel, purchased energy and purchased gas expenses and other factors.


Certain amounts in the 2002 Consolidated Financial Statements have been reclassified to conform to the 2003 presentation.


Stock Compensation

The following table illustrates the pro forma effect on net income (loss) and earnings per share if Dominion had applied the fair value recognition provisions of Statement of Financial Accounting Standards (SFAS) No. 123, Accounting for Stock-Based Compensation, to stock-based employee compensation:

 

 

Three Months Ended
September 30,

Nine Months Ended
September 30,

2003

2002

2003

2002

 

(millions)

Net income (loss), as reported

$(256)

$430 

$492 

$1,024 

Add: actual stock-based compensation expense, net of tax

Deduct: pro forma stock-based compensation expense, net of tax

      (7)

  (11)

   (28)

  (41)

Net income (loss), pro forma

$(261)

$420 

$472 

$987 

 

 

 

 

 

Basic earnings (loss) per share - as reported

$(0.79)

$1.55 

$1.56 

$3.73 

Basic earnings (loss) per share - pro forma

$(0.81)

$1.51 

$1.50 

$3.60 

 

 

 

 

 

Diluted earnings (loss) per share - as reported

$(0.79)

$1.54 

$1.56 

$3.71 

Diluted earnings (loss) per share - pro forma

$(0.81)

$1.50 

$1.49 

$3.57 

PAGE 9

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Note 3.     Newly Adopted Accounting Standards


Accounting for Asset Retirement Obligations

Effective January 1, 2003, Dominion adopted SFAS No. 143, Accounting for Asset Retirement Obligations, which provides accounting requirements for the recognition and measurement of liabilities associated with the retirement of tangible long-lived assets. Dominion has identified certain asset retirement obligations that are subject to the standard. These obligations are primarily associated with the decommissioning of its nuclear generation facilities, abandoning certain natural gas pipelines and dismantling and removing gas and oil wells and platforms.


In addition, Dominion has identified asset retirement obligations related to its natural gas gathering, storage, transmission and distribution systems, including approximately 2,300 gas storage wells in Dominion's underground natural gas storage network. These obligations result from certain safety requirements to be performed at the time any pipeline or storage well is abandoned. However, Dominion expects to operate its natural gas gathering, storage, transmission and distribution systems in perpetuity. Thus, such asset retirement obligations will not be reflected in Dominion's Consolidated Financial Statements until sufficient information becomes available to determine a reasonable estimate of the fair value of the activities to be performed. Generally, this will occur based on expected retirement or abandonment of individual pipelines or storage wells based on Dominion's operational planning.


The effect of adopting SFAS No. 143 for the three and nine months ended September 30, 2003, as compared to an estimate of net income reflecting the continuation of former accounting policies, was to increase net income by $3 million and $194 million for those periods, respectively. The $194 million increase for the nine months ended September 30, 2003 is comprised of a $180 million after-tax gain, representing the cumulative effect of a change in accounting principle and an increase in income before the cumulative effect of a change in accounting principle of $14 million.


Accounting for Energy Trading Contracts

In 2002, the Emerging Issues Task Force (EITF) reached consensus on EITF Issue No. 02-3, Issues Involved in Accounting for Derivative Contracts Held for Trading Purposes and Contracts Involved in Energy Trading and Risk Management Activities. As a result, certain energy-related commodity contracts that are held in connection with Dominion's energy trading activities are no longer subject to fair value accounting. The affected contracts are those energy-related contracts that are not considered to be derivatives under SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities. Energy-related contracts affected by this change are now subject to accrual accounting and recognized as revenue or expense at the time of contract performance, settlement or termination. The new rules were effective for energy-related contracts initiated prior to October 25, 2002 as of January 1, 2003, and required that Dominion record a cumulative effect of a change in accountin g principle, resulting in an after-tax loss of $67 million.


EITF 02-3 also affects the classification of gains and losses arising from derivative energy contracts no longer considered to be held for trading purposes. Under the provisions of EITF 02-3, for those energy-related derivative instruments determined to be held for trading purposes, all changes in fair value, including amounts realized upon settlement, continue to be presented in revenue on a net basis. A derivative contract is held for trading purposes if the intent of the transaction is to generate profits on short-term differences in price. For non-trading derivatives not designated as hedges, all unrealized changes in fair value are presented in other operations and maintenance expense on a net basis. For non-trading derivative contracts that involve physical delivery of commodities, gross sales contract settlements are presented in revenue, while gross purchase contract settlements are reported in expenses.

PAGE 10

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Accounting for Certain Financial Instruments with Characteristics of Both Liabilities and Equity

Effective July 1, 2003, Dominion adopted SFAS No. 150, Accounting for Certain Financial Instruments with Characteristics of Both Liabilities and Equity. The standard requires an issuer to classify certain financial instruments with characteristics of both liabilities and equity as a liability if the issuer is obligated to redeem such instruments. As a result, beginning July 1, 2003, Dominion presents the mandatorily redeemable preferred securities issued by its subsidiary trusts as long-term debt and related distributions as interest expense. These securities are described in Note 22 to the Consolidated Financial Statements for the year ended December 31, 2002.


Amendment of SFAS No. 133

During the second quarter of 2003, the Financial Accounting Standards Board (FASB) issued SFAS No. 149, Amendment of Statement 133 on Derivative Instruments and Hedging Activities. SFAS No. 149 reflects decisions made by FASB and its Derivatives Implementation Group in connection with issues raised about the application of SFAS No. 133. Generally, changes resulting from SFAS No. 149 apply to contracts entered into or modified after June 30, 2003 and for hedging relationships designated after June 30, 2003. Although industry efforts to interpret SFAS No. 149 are ongoing, Dominion believes that SFAS 149 will not have a material impact on its results of operations and financial position based on an assessment of currently available information.

Note 4.     Recently Issued Accounting Standards and Other Accounting Matters

Consolidation of Variable Interest Entities

In January 2003, FASB issued Interpretation No. 46, Consolidation of Variable Interest Entities, (FIN 46) which addresses the consolidation of "variable interest entities" (VIEs). VIEs are entities that are not controllable through voting interests or in which the equity investors do not bear the residual economic risks and rewards. In October 2003, FASB decided to permit more time for the implementation of FIN 46 and now requires adoption as of December 31, 2003.


Leases with Special Purpose Entities

Dominion, through certain subsidiaries, has entered into agreements with VIEs in order to finance and lease several new power generation projects, as well as its corporate headquarters and aircraft. Neither the project assets nor the related obligations are currently reported on Dominion's Consolidated Balance Sheets under existing accounting guidance.


Dominion estimates that consolidating those VIEs for which it is the primary beneficiary under FIN 46, effective December 31, 2003, will result in an additional $647 million in net property, plant and equipment and $688 million of related debt. The cumulative effect of adopting FIN 46 is estimated to result in an after-tax charge of $25 million, representing depreciation expense associated with the consolidated assets.


At September 30, 2003, Dominion's maximum exposure to loss resulting from its interests in VIEs is $567 million based upon total project costs. The exposure assumes the property, plant and equipment will have no value at the end of their lease terms, which management believes is highly unlikely.


Trust Preferred Securities

Dominion established five capital trusts that sold trust preferred securities to third party investors. Dominion received the proceeds from the sale of the trust preferred securities in exchange for various junior subordinated debt instruments issued by Dominion to be held by the trusts. Under existing accounting guidance, Dominion consolidates the trusts in the preparation of its Consolidated Financial Statements. Under FIN 46, Dominion will cease consolidating the trusts beginning on December 31, 2003. Upon adoption, Dominion's Consolidated Balance Sheets will report the junior subordinated instruments held by the trusts as long-term debt, rather than the trust preferred securities.

PAGE 11

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Other SFAS No. 133 Guidance

In connection with a request to reconsider an interpretation of SFAS No. 133, FASB issued Statement 133 Implementation Issue No. C20, Interpretation of the Meaning of 'Not Clearly and Closely Related' in Paragraph 10(b) regarding Contracts with a Price Adjustment Feature. Under C20, criteria are established to determine if a contract's pricing terms that contain broad market indices (e.g., the consumer price index) could qualify as a normal purchase or sale and therefore not be subject to fair value accounting. Dominion has several contracts that are subject to the C20 guidance. Dominion estimates the cumulative effect of adopting C20 to be an after-tax charge of approximately $75 million, representing the fair value of contracts as of October 1, 2003. Price adjustments in these contracts satisfy the normal purchase and sale criteria as defined under C20.


Balance Sheet Classification - Mineral Rights

Companies with gas and oil exploration and production operations have become aware that a question has arisen about whether contractual mineral rights should be classified as intangible assets rather than tangible assets on the balance sheet as a result of SFAS Nos. 141, Business Combinations, and 142, Goodwill and Other Intangible Assets. If, as a result of the resolution of this issue, reclassification of the costs associated with its mineral rights is required, Dominion's net intangible assets would increase and its net property, plant and equipment would decrease. As of September 30, 2003, the amount subject to reclassification was approximately $4.0 billion. While resolution of this issue may affect the balance sheet classification of these assets, there would be no impact on Dominion's results of operations or cash flows.

Balance Sheet Classification - Provision for Future Cost of Removal by Regulated Operations

Dominion adopted SFAS No. 143 on January 1, 2003. SFAS No. 143 provides accounting requirements for the recognition and measurement of liabilities associated with the retirement of tangible long-lived assets.


In accordance with applicable regulatory uniform system of accounts and as permitted by SFAS No. 71, Accounting for the Effects of Certain Types of Regulation, Dominion's gas and electric utility operations recognize a provision for the cost of future asset removal activities subject to cost-of-service rate regulation, even if no legal obligation to perform such activities exists. The periodic provision is recorded as a component of depreciation expense on the income statement, resulting in a credit being recorded in accumulated depreciation, depletion and amortization on the balance sheet. At September 30, 2003 and December 31, 2002, Dominion's accumulated depreciation, depletion and amortization included $563 million and $596 million, respectively, representing regulatory liabilities for the estimated amounts collected from customers for the future cost of such asset removal activities.


A question has recently arisen about whether these regulatory liabilities should continue to be classified in accumulated depreciation, depletion and amortization or be reported as liabilities on the balance sheet. If, as a result of the resolution of this issue, reclassification of this accumulated provision for future removal costs is required, Dominion's accumulated depreciation would decrease and its regulatory liabilities would increase. While resolution of this issue may affect the balance sheet classification of these items, there would be no impact on Dominion's results of operations or cash flows.

PAGE 12

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Note 5.     Operating Revenue

 

Three Months Ended
September 30,

Nine Months Ended
September 30,

2003

2002

2003

2002

Operating Revenue

(millions)

Regulated Sales

 

 

 

 

  Electric

$1,383

$1,453

$3,742

$3,729

  Gas

121

82

851

542

Nonregulated Sales

 

 

 

 

  Electric

316

266

915

742

  Gas

311

117

1,268

528

Gas transportation and storage

138

125

539

492

Gas and oil production

376

331

1,135

976

Other

     212

     171

     627

     503

        Total operating revenue

$2,857

$2,545

$9,077

$7,512

The composition of revenue from nonregulated electric sales, nonregulated gas sales and other revenue has changed effective January 1, 2003. For non-trading derivatives not designated as hedges, all unrealized changes in fair value are presented in other operations and maintenance expense on a net basis. For non-trading derivative contracts that involve physical delivery of commodities, gross sales contract settlements are presented in revenue, while gross purchase contract settlements are reported in expenses.

Note 6.     Income Taxes


A comparison and analysis of the effective tax rate for the three and nine months ended September 30, 2003 and 2002 is presented below:

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

2003

 

2002

 

2003

 

2002

 

(millions)

Income (loss) before income taxes and minority
  interests


$(10)

 

 


$641 

 

 


$946 

 

 


$1,549 

 

Less: Impairment losses not currently deductible(1)

527 

 

 

   -- 

 

 

527 

 

 

   -- 

 

Income before income taxes - adjusted

517 

 

 

641 

 

 

1,473 

 

 

1,549 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income taxes at U.S. statutory rate

181 

35%

 

224 

35%

 

515 

35%

 

542 

35%

Changes in valuation allowance(2)

53 

10    

 

 -- 

 --   

 

53 

4    

 

 -- 

 --    

State taxes(3)

22 

4    

 

(1)

 --   

 

48 

3    

 

37 

 2    

Nonconventional fuel credit (4)

 -- 

 --    

 

(11)

(2)  

 

 -- 

 --    

 

(28)

(2)  

Other, net

  (5)

 (1)   

 

    (1)

 --   

 

(23)

 (2)   

 

    (26)

 (1)  

Income tax expense

$251 

48%

 

$211 

33%

 

$593

40%

 

$525 

34%

________________

(1)   Represents impairment of telecommunications assets; realization of tax benefits will be dependent on Dominion's future tax profile and taxable earnings.

(2)   Relates primarily to deferred tax assets of Dominion's telecommunications investment and financial services subsidiary. The valuation allowance was increased as Dominion considers it "more likely than not" that those deferred tax assets will not be realized.

(3)   Amounts for 2002 reflect the effect of including certain subsidiaries in Dominion's consolidated state income tax returns.

(4)   Nonconventional fuel credits were not available after January 1, 2003.

 

PAGE 13

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Note 7.     Earnings Per Share

The following table presents the calculation of Dominion's basic and diluted earnings per share (EPS):

Three Months Ended
September 30,

Nine Months Ended
September 30,

2003

2002

2003

2002

(millions, except per share amounts)

Income (loss) before cumulative effect of changes in accounting principle

$(256)

$430

$379

$1,024

Cumulative effect of changes in accounting principle

       -- 

      --

   113

       --

Net income (loss)

$(256)

$430

$492

$1,024

Basic EPS

Average shares of common stock outstanding - basic

322.8

278.3

315.3

274.2

Income (loss) before cumulative effect of changes in accounting principle

$(0.79)

$1.55

$1.20

$3.73

Cumulative effect of changes in accounting principle

        -- 

      --

  0.36

      --

Net income (loss)

$(0.79)

$1.55

$1.56

$3.73

Diluted EPS

Average shares of common stock outstanding

322.8

278.3

315.3

274.2

Net effect of dilutive stock options (1)(2)

         --

     1.4

    1.3

    1.9

Average shares of common stock outstanding - diluted

  322.8

 279.7

316.6

276.1

Income (loss) before cumulative effect of changes in accounting principle

$(0.79)

$1.54

$1.20

$3.71

Cumulative effect of changes in accounting principle

        -- 

      --

  0.36

      --

Net income (loss)

$(0.79)

$1.54

$1.56

$3.71

Average antidilutive shares excluded from the EPS calculation(2)

24.0

9.4

11.1

5.7

________________

(1)  Represents the effect of "in-the-money" stock options on the calculation of average outstanding shares of common stock.

(2)  As result of the net loss for the three months ended September 30, 2003, the issuance of common stock under potentially-dilutive securities was considered antidilutive and therefore not included in the calculation of the diluted loss per share for that period.

Note 8.     Comprehensive Income (Loss)


The following table presents total comprehensive income (loss):

 

Three Months Ended
September 30,

Nine Months Ended
September 30,

 

2003

2002

2003

2002

 

(millions)

Net income (loss)

$(256)

$430 

$492 

$1,024 

Other comprehensive income (loss)(1)

   209 

 (120)

  (96)

  (582)

Total comprehensive income (loss)

$  (47)

$310 

$396 

$  442 

________________

(1) Represents primarily the effective portion of changes in fair value of derivatives designated as cash flow hedges and unrealized gains and losses on investments held in decommissioning trusts.

 

 

PAGE 14

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Note 9.     Derivatives and Hedge Accounting


Selected information about Dominion's hedge accounting activities follows:

 

Three Months Ended September 30,

Nine Months Ended September 30,

 

2003

2002

2003

2002

Portion of pre-tax gains (losses) on hedging instruments determined to be ineffective and included in net income (loss):

(millions)

   Fair value hedges

$(4)

$(1)

$(1)

$  2 

   Cash flow hedges

   2 

   (4)

   (1)

   (21)

Net ineffectiveness

$(2)

$(5)

$(2)

$(19)

 

 

 

 

 

For options used as hedging instruments, change in options' time value excluded from measurement of effectiveness and included in net income (loss):

 

 

 

 

   Fair value hedges

$1 

--

$1

$(1)

   Cash flow hedges

 (3)

   --

  5

   -- 

Total change in options' time value

$(2)

   --

$6

$(1)

 

 

 

 

 

Other comprehensive income (loss), net of taxes - cash flow hedges


$237


$(19)


$(208)


$(477)

The following table presents selected information related to cash flow hedges included in accumulated other comprehensive income in the Consolidated Balance Sheet at September 30, 2003:

Accumulated Other
Comprehensive
Income (Loss)
After Tax

Portion Expected to be
Reclassified to
Earnings during the
Next 12 Months




Maximum Term

(millions)

Commodities

$(566)

$(220)

53 months

Interest rate

(27)

(1)

273 months

Foreign currency

      28 

        3 

50 months

Total

$(565)

$(218)


The actual amounts that will be reclassified to earnings during the next 12 months will vary from the expected amounts presented above as a result of changes in market prices, interest rates and foreign exchange rates. The effect of amounts being reclassified from accumulated other comprehensive income to earnings will generally be offset by the recognition of the hedged transactions (e.g., anticipated sales) in earnings, thereby achieving the realization of prices contemplated by the underlying risk management strategies.

 

PAGE 15

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Note 10.     Goodwill


The changes in the carrying amount of goodwill for the nine months ended September 30, 2003, are as follows:



Dominion Energy


Dominion Delivery


Dominion E&P


Corporate
and Other



Total

(millions)

Balance at December 31, 2002

$2,057

$1,344 

$879

$21

$4,301

  Acquisition of controlling interest in a previously unconsolidated subsidiary of Dominion Capital, Inc. (DCI)



- --



- -- 



- --



27



27

  Reallocation of goodwill due to transfer of electric transmission operations from Dominion Delivery to Dominion Energy



    168



   (168
)



     --



    --



        --

Balance at September 30, 2003

$2,225

$1,176 

$879

$48

$4,328

Note 11.     Ceiling Test


Dominion follows the full cost method of accounting for gas and oil exploration and production activities, as prescribed by the SEC. Under this method, capitalized costs are subject to a quarterly "ceiling test." Under the ceiling test, amounts capitalized are limited to the present value of estimated future net revenues to be derived from the anticipated production of proved gas and oil reserves, assuming period-end market prices. Approximately 15 percent of Dominion's anticipated production is hedged by qualifying cash flow hedges, for which hedge-adjusted prices were used to calculate estimated future net revenue. Whether period-end market prices or hedge-adjusted prices were used for the portion of production that is hedged, there was no ceiling test impairment as of September 30, 2003.

Note 12.     Significant Financing Transactions


Credit Facilities and Short-Term Debt

Dominion, Virginia Power and CNG (the Dominion Companies) use short-term debt, primarily commercial paper, to fund working capital requirements and as bridge financing for acquisitions. The levels of borrowing may vary significantly during the course of the year, depending upon the timing and amount of cash requirements not satisfied by cash from operations. The commercial paper programs are supported by various credit facilities as discussed below. At September 30, 2003, the Dominion Companies had the following short-term debt outstanding and capacity available under credit facilities:



Facility Limit

Outstanding Commercial Paper

Outstanding Letters of Credit

Facility Capacity Available

(millions)

364-day joint revolving credit facility

$1,250

Three-year joint revolving credit facility

     750

  Total joint credit facilities(1)

2,000

$875

$88

$1,037

364-day CNG credit facility(2)

  1,000

     --

  586

     414

     Totals

$3,000

$875

$674

$1,451

__________________________

(1) The joint credit facilities support borrowings by the Dominion Companies. The 364-day revolving credit facility was executed in May 2003 and terminates in May 2004. The three-year revolving credit facility was executed in May 2002 and terminates in May 2005.

(2) The credit facility is used to support the issuance of letters of credit and commercial paper by CNG to fund collateral requirements under its gas and oil hedging program. The facility was executed in August 2003 and terminates in August 2004.

PAGE 16

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Long-Term Debt

During the nine months ended September 30, 2003, Dominion Resources, Inc. and its subsidiaries issued the following long-term debt:

Type

Principal

Rate

Maturity

Issuing Company

 

(millions)

 

 

 

Senior notes

$1,810 

2.80% to 6.30%

2005 to 2033

Dominion Resources, Inc.

Senior notes

500 

Variable

2013

Dominion Resources, Inc.

Senior notes

     400 

4.75%

2013

Virginia Power

  Total long-term debt issued

$2,710 

 

 

 

  Less: direct exchange(1)

   (500)

 

 

 

  Total long-term debt issued, excluding direct exchanges


$2,210 

 

 

 

____________________

(1) During the third quarter of 2003, Dominion redeemed its $500 million variable rate senior notes due 2013. In a direct exchange, Dominion completed the redemption by issuing $510 million of 5.25 percent senior notes due 2033.


In addition to the senior notes described above, during the third quarter, Dominion borrowed $18 million to complete a power generation project at Virginia Power's Possum Point power station.


During the nine months ended September 30, 2003, Dominion Resources, Inc. and its subsidiaries repaid $2.0 billion of long-term debt securities. Dominion used the entirety of its $500 million escrow deposit, established in December 2002, to repay matured debt in January 2003.


Issuance of Common Stock

During the nine months ended September 30, 2003, Dominion received proceeds of $253 million through Dominion Direct (a dividend reinvestment and open enrollment direct stock purchase plan), employee savings plans and the exercise of employee stock options. In addition, during the second quarter of 2003, Dominion received proceeds of $683 million through a public equity offering.

Note 13.     Asset Retirement Obligations


The following table describes the changes to Dominion's asset retirement obligations during the nine months ended September 30, 2003:

 

Amount

 

(millions)

Asset retirement obligations at January 1, 2003

-- 

  Asset retirement obligations recognized in transition

$1,543 

  Asset retirement obligations incurred during the period

  Asset retirement obligations settled during the period

(19)

  Accretion expense

64 

  Revisions in estimated cash flows

(2)

  Other

          5 

Asset retirement obligations at September 30, 2003(1)

$1,598 

__________________________

(1) Amount includes $2 million reported in other current liabilities.

Dominion has established external trusts dedicated to funding the future decommissioning of its nuclear plants. At September 30, 2003, the aggregate fair value of these trusts, consisting primarily of debt and equity securities, totaled $1.8 billion.

PAGE 17

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Had the provisions of SFAS No. 143 been applied for the following periods in 2003 and 2002, Dominion's net income and earnings per share would have been as follows:

Amount

Basic EPS

Diluted EPS

 

(in millions, except per share amounts)

For the Three Months Ended:

 

 

 

September 30, 2003

 

 

 

Reported net income (loss)

$(256)

$(0.79)

$(0.79)

Adjusted net income (loss)

$(256)

$(0.79)

$(0.79)

 

 

 

 

September 30, 2002

 

 

 

Reported net income

$430

$1.55

$1.54

Adjusted net income

$432

$1.56

$1.55

 

 

 

 

For the Nine Months Ended:

 

 

 

September 30, 2003

 

 

 

Reported net income

$492

$1.56

$1.56

Adjusted net income

$312

$0.99

$0.99

 

 

 

 

September 30, 2002

 

 

 

Reported net income

$1,024

$3.73

$3.71

Adjusted net income

$1,033

$3.76

$3.74

Note 14.     Commitments and Contingencies


Other than the matters discussed below, there have been no significant developments regarding the commitments and contingencies disclosed in Note 27 to the Consolidated Financial Statements for the year ended December 31, 2002, nor have any significant new matters arisen during the nine months ended September 30, 2003.


Fuel Purchase Commitments

Dominion enters into long-term purchase commitments for fuel used in electric generation and natural gas for purposes other than trading. As of September 30, 2003, estimated payments under these commitments are as follows: 2004-$550 million; 2005-$385 million; 2006-$235 million; 2007-$130 million; and years beyond 2007-$215 million. These purchase commitments include those required for regulated operations. Dominion recovers the costs of those purchases through regulated rates. The natural gas purchase commitments of Dominion's field services operations are also included, net of related sales commitments.


Leases with Special Purpose Entities

Dominion, through certain subsidiaries, has entered into agreements with VIEs in order to finance and lease several new power generation projects, as well as its corporate headquarters and aircraft. The VIEs have financing commitments from equity and debt investors totaling $1.9 billion, of which approximately $1.7 billion has been used for project costs incurred to date. At September 30, 2003, under existing accounting guidance, approximately $1.3 billion of project assets and related debt were not reported on Dominion's Consolidated Balance Sheets.

PAGE 18

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


During the second quarter of 2003, for one of the power generation projects under construction, Dominion entered into a new arrangement with a non-affiliated "voting interest entity". The voting interest entity will not be consolidated by Dominion under FIN 46. Project costs totaled $626 million at September 30, 2003 for this project, of which $560 million was advanced by Dominion. This project is expected to be completed in 2004 and will result in estimated annual lease commitments of approximately $58 million.


On December 31, 2003, Dominion will consolidate the VIEs for which it has been determined to be the primary beneficiary under FIN 46. As a result, previously disclosed annual future minimum lease commitments will be reduced by approximately $38 million. A similar amount will be recognized annually as interest expense associated with the newly consolidated debt obligations.


Environmental Matters

In relation to a Notice of Violation received by Virginia Power in 2000 from the U.S. Environmental Protection Agency (EPA) and related proceedings, Virginia Power, the U.S. Department of Justice, the EPA, the states of Virginia, West Virginia, Connecticut, New Jersey and New York agreed to a settlement in April 2003 in the form of a proposed Consent Decree. The Virginia federal district court entered the final Consent Decree in October 2003, resolving the underlying actions. The settlement includes payment of a $5 million civil penalty, an obligation to fund $14 million for environmental projects and a commitment to improve air quality under the Consent Decree estimated to involve expenditures of $1.2 billion. Dominion has already incurred certain capital expenditures for environmental improvements at its coal-fired stations in Virginia and West Virginia and has committed to additional measures in its current financial plans and capital budget to satisfy the requirements of the Co nsent Decree. As of September 30, 2003, Dominion had accrued $19 million for the civil penalty and the funding of the environmental projects, substantially all of which was recorded in 2000.


Guarantees, Letters of Credit and Surety Bonds

On behalf of consolidated subsidiaries, as of September 30, 2003, Dominion and its subsidiaries had issued $6.8 billion of guarantees, including: $3.0 billion to support commodity transactions of subsidiaries; $1.3 billion for subsidiary debt; $1.3 billion related to leasing obligations for new power generation projects, corporate headquarters and aircraft; and $1.2 billion for guarantees supporting other agreements of subsidiaries. Dominion had also purchased $122 million of surety bonds and authorized the issuance of standby letters of credit by financial institutions of $703 million. Dominion enters into these arrangements to facilitate commercial transactions by its subsidiaries with third parties. To the extent a liability subject to a guarantee has been incurred by a consolidated subsidiary, that liability is included in Dominion's Consolidated Financial Statements. Dominion believes it is unlikely that it would be required to perform or otherwise incur any losses associated with guarantees of its subsidiaries' obligations.

Note 15.     Concentration of Credit Risk


Dominion calculates its gross credit exposure for each counterparty as the unrealized fair value of derivative and energy trading contracts plus any outstanding receivables (net of payables, where netting agreements exist), prior to the application of collateral.

 

PAGE 19

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Presented below is a summary of Dominion's gross and net credit exposure as of September 30, 2003. The amounts presented exclude accounts receivable for retail electric and gas sales and services, regulated transmission services and Dominion's provision for credit losses. See Note 29 to the Consolidated Financial Statements for the year ended December 31, 2002 for a discussion of the nature of Dominion's credit risk exposures.

 

 

At September 30, 2003



 

Credit Exposure
before
Credit Collateral

 


Credit
Collateral

 

Net
Credit
Exposure

 

 

(millions)

Investment grade(1)

 

$585

 

$31

 

$554

Non-investment grade(2)

 

44

 

13

 

31

No external ratings:

 

 

 

 

 

 

  Internally rated - investment grade(3)

 

285

 

--

 

285

  Internally rated - non-investment grade(4)

 

     160

 

   --

 

      160

   Total

 

$1,074

 

$44

 

$1,030

_______________________

(1) This category includes counterparties with minimum credit ratings of Baa3 assigned by Moody's Investor Service (Moody's) and BBB- assigned by Standard & Poor's Rating Group, a division of the McGraw-Hill Companies, Inc. (Standard & Poor's). The five largest counterparty exposures, combined, for this category represented approximately 15 percent of the total gross credit exposure.

(2) This category includes counterparties with credit ratings that are below investment grade. The five largest counterparty exposures, combined, for this category represented approximately 2 percent of the total gross credit exposure.

(3) This category includes counterparties that have not been rated by Moody's or Standard & Poor's, but are considered investment grade based on Dominion's evaluation of the counterparty's creditworthiness. The five largest counterparty exposures, combined, for this category represented approximately 20 percent of the total gross credit exposure.

(4) This category includes counterparties that have not been rated by Moody's or Standard & Poor's, and are considered non-investment grade based on Dominion's evaluation of the counterparty's creditworthiness. The five largest counterparty exposures, combined, for this category represented approximately 4 percent of the total gross credit exposure.

Note 16.     Dominion Fiber Ventures, LLC (DFV)

Dominion has a membership interest in DFV, a joint venture with a third-party investor trust (Investor Trust). DFV was established to fund the development of its principal investment, Dominion Telecom, Inc. (DTI), a telecommunications business. DTI is a facilities-based interchange and emerging local carrier that provides broadband solutions to wholesale customers throughout the eastern United States.

Impairment and Other Charges

Third Quarter 2003

At inception, Dominion's strategy for its telecommunications investment was to focus primarily on delivering lit capacity, dark fiber and collocation services to under-served markets. With the markets for these services not growing at rates originally contemplated and the continuing downward pressure on prices, resulting from excess capacity in the telecommunications industry, Dominion reconsidered its investment strategy during the third quarter of 2003. Reflecting a revision in long-term expectations for potential growth in telecommunications service revenue, Dominion approved a strategy to sell its interest in the telecommunications business. The strategy included a review of DTI's network assets and related inventories for impairment. As a result, Dominion recognized a $527 million write-down of network assets and related inventories to estimated fair value based on an independent appraisal. Appraised values included a combination of prices observed for sales of similar assets and discounted cash flow estimates. Dominion has not recognized any deferred tax benefits related to the impairment charges, since realization of tax benefits will be dependent upon Dominion's future tax profile and taxable earnings. In addition, Dominion increased the valuation allowance on deferred tax assets previously recognized in connection with its telecommunications investment, resulting in a $48 million increase in deferred income tax expense. These charges are reflected in the net expenses of Corporate and Other.

PAGE 20

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Dominion expects to formalize the plan of divestiture for DTI and anticipates presenting DTI's assets as held-for-sale and its results of operations as discontinued operations beginning at that time.


First Quarter 2003

During the first quarter of 2003, Dominion recognized a pre-tax charge of $60 million associated with its DFV investment and reported the charge as other expense on the Consolidated Statement of Income. This included a $27 million charge for the reallocation of DFV's equity losses between the Investor Trust and Dominion. Based on current projections of DFV's expected net losses, Dominion and the Investor Trust revised the allocation of equity losses, using cash allocations and liquidation provisions of the underlying limited liability company agreement rather than voting interests. The charge also included a $33 million impairment charge in connection with certain assets that will no longer be used under a business plan implemented in 2003. Dominion's share of the impairment, after allocation of the minority interest share to the Investor Trust, was $17 million.

Acquisition of DFV Senior Notes

In connection with its formation, DFV issued $665 million of 7.05 percent senior secured notes due March 2005. Dominion purchased $633 million of the outstanding notes in February 2003, using $664 million of the proceeds from the sale of $700 million of senior notes. As a result of this transaction, Dominion consolidated the results of DFV in its Consolidated Financial Statements beginning in February 2003. Dominion recognized a pre-tax charge of $57 million on the effective extinguishment of the acquired DFV senior notes.

Note 17.     Other Asset Impairments


During the third quarter of 2003, Dominion recognized a $14 million ($9 million after-tax) impairment of retained interests from mortgage securitizations held by DCI, Dominion's financial services subsidiary, reflecting increased defaults and accelerated prepayments as a result of low interest rates. In addition, Dominion increased the valuation allowance on a deferred tax asset associated with a DCI investment, resulting in a $12 million increase in deferred tax expense.


During the second quarter of 2003, Dominion recognized an impairment loss of $40 million ($25 million after-tax) related to certain assets classified as held-for-sale and reported in other current assets. The assets included a small generation facility located in Kauai, Hawaii and an equity investment in a pipeline business located in Australia. The impairment loss represented an adjustment to the assets' carrying amounts to reflect Dominion's current evaluation of fair value less estimated costs to sell.

Note 18.     Volumetric Production Payment Transaction


In August 2003, Dominion received $266 million in cash for the sale of a fixed-term overriding royalty interest in certain of its natural gas reserves for the period August 2003 through August 2007. The sale reduced Dominion's natural gas reserves by approximately 66 billion cubic feet (bcf). While the Company is obligated under the agreement to deliver to the purchaser its portion of future natural gas production from the properties, it retains control of the properties and rights to future development drilling. If production from the properties is inadequate to deliver approximately 66 bcf of natural gas scheduled for delivery to the purchaser, Dominion has no obligation to make up the shortfall. Cash proceeds received from this volumetric production payment transaction were recorded as deferred revenue. Dominion will recognize revenue from the transaction as natural gas is produced and delivered to the purchaser.

PAGE 21

DOMINION RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)


Note 19.     Operating Segments


Dominion manages its operations along three primary business lines:

Dominion Energy manages Dominion's electric generation portfolio, gas transmission and storage operations and certain gas production. It also manages Dominion's energy trading, marketing, hedging and arbitrage activities and its retail marketing of non-regulated energy services. Effective January 1, 2003, Dominion Energy also manages Dominion's electric transmission operations formerly managed by Dominion Delivery. Amounts for 2002 have been restated to reflect the management of electric transmission by Dominion Energy effective January 1, 2003.


Dominion Delivery
manages Dominion's electric and gas distribution systems as well as Dominion's investment in DFV. Amounts for 2002 have been restated to reflect the management of electric transmission by Dominion Energy effective January 1, 2003.


Dominion Exploration & Production
manages Dominion's gas and oil exploration, development and production operations. These operations are located in several major producing basins in the lower 48 states, including the outer continental shelf and deep-water areas of the Gulf of Mexico, and Western Canada.


In addition, Dominion also reports the operations of DCI and Dominion's corporate and other operations as a segment. Amounts included in Corporate and Other for the three and nine months ended September 30, 2003 and 2002 include corporate expenses of the Dominion and CNG holding companies (including interest and other expenses not allocated to other segments) as well as the following items attributable to activities of the other segments:






Dominion Energy



Dominion Delivery


Dominion Exploration & Production



Corporate and Other




Eliminations



Consolidated Total

Three Months Ended September 30,

(millions)

2003

 

 

 

 

 

 

Operating revenue - external customers

$1,866

$490

$ 460

$41 

--

$2,857 

Operating revenue - inter-segment

60

5

37

140 

$(242)

-- 

Net income (loss)

296

80

98

(730)

 

(256)

2002

 

 

 

 

 

 

Operating revenue - external customers

1,628

451

409

57 

--

2,545 

Operating revenue - inter-segment

29

6

22

142 

(199)

-- 

Net income (loss)

297

87

90

(44)

 

430 

 

 

Nine Months Ended September 30,

 

2003

 

 

 

 

 

 

Operating revenue - external customers

$5,586

$1,982

$1,400

$109 

--

$9,077 

Operating revenue - inter-segment

181

14

120

446 

$(761)

-- 

Net income (loss)

747

291

299

(845)

 

492 

2002

 

 

 

 

 

 

Operating revenue - external customers

4,529

1,610

1,202

171 

--

7,512 

Operating revenue - inter-segment

85

17

62

424 

(588)

-- 

Net income (loss)

641

274

271

(162)

 

1,024 

 

PAGE 22

DOMINION RESOURCES, INC.

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


Introduction


Management's Discussion and Analysis of Financial Condition and Results of Operations (MD&A) discusses the results of operations and general financial condition of Dominion. MD&A should be read in conjunction with the Consolidated Financial Statements. The term "Dominion" is used throughout MD&A and, depending on the context of its use, may represent any of the following: the legal entity, Dominion Resources, Inc.; one of Dominion Resources, Inc.'s consolidated subsidiaries; or the entirety of Dominion Resources, Inc. and its consolidated subsidiaries.

On May 9, 2003, Dominion filed a current report on Form 8-K that included its Consolidated Financial Statements and Notes for the year ended December 31, 2002, as well as certain portions of MD&A, which were reformatted to reflect the transfer of electric transmission operations to Dominion Energy from Dominion Delivery effective January 1, 2003. References to the Consolidated Financial Statements and Notes for the year ended December 31, 2002 refer to those included in the May 9, 2003 current report on Form 8-K.


Risk Factors and Cautionary Statements That May Affect Future Results


This report contains statements concerning Dominion's expectations, plans, objectives, future financial performance and other statements that are not historical facts. These statements are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. In most cases, the reader can identify these forward-looking statements by words such as "anticipate," "estimate," "forecast," "expect," "believe," "should," "could," "plan," "may" or other similar words.


Dominion makes forward-looking statements with full knowledge that risks and uncertainties exist that may cause actual results to be materially different from predicted results. Factors that could cause actual results to differ are often presented with the forward-looking statements themselves. In addition, other factors could cause actual results to differ materially from those indicated in any forward-looking statement. These factors include weather conditions; governmental regulations; cost of environmental compliance; inherent risk in the operation of nuclear facilities; fluctuations in energy-related commodities prices and the effect these could have on Dominion's earnings, liquidity position and the underlying value of its assets; trading counterparty credit risk; capital market conditions, including price risk due to marketable securities held as investments in trusts and benefit plans; fluctuations in interest rates; changes in rating agency requirements or ratings; changes in acc ounting standards; the risks of operating businesses in regulated industries that are becoming deregulated; the transfer of control over electric transmission facilities to a regional transmission organization; completing the divestiture of investments held by DCI, CNG International Corporation and DFV; collective bargaining agreements and labor negotiations; and political and economic conditions (including inflation and deflation). More specific risks are discussed below.


Dominion bases its forward-looking statements on management's beliefs and assumptions using information available at the time the statements are made. Dominion cautions the reader not to place undue reliance on its forward-looking statements because the assumptions, beliefs, expectations and projections about future events may, and often do, materially differ from actual results. Dominion undertakes no obligation to update any forward-looking statement to reflect developments occurring after the statement is made.


Dominion's operations are weather sensitive.
Dominion's results of operations can be affected by changes in the weather. Weather conditions directly influence the demand for electricity and natural gas and affect the price of energy commodities. In addition, severe weather, including hurricanes, winter storms and droughts, can be destructive, causing outages, production delays and property damage that require Dominion to incur additional expenses.


Dominion is subject to complex governmental regulation that could adversely affect its operations.
    Dominion's operations are subject to extensive regulation and require numerous permits, approvals and certificates from federal, state and local governmental agencies. Dominion must also comply with environmental legislation and other regulations. Management believes the necessary approvals have been obtained for Dominion's existing operations and that its business is conducted in accordance with applicable laws. However, new laws or regulations, or the revision or reinterpretation of existing laws or regulations, may require Dominion to incur additional expenses.

PAGE 23

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Costs of environmental compliance, liabilities and litigation could exceed Dominion's estimates.
Compliance with federal, state and local environmental laws and regulations may result in increased capital, operating and other costs, including remediation and containment and monitoring obligations. In addition, Dominion may be a responsible party for environmental clean-up at a site identified by a regulatory body. Management cannot predict with certainty the amount and timing of all future expenditures related to environmental matters because of the difficulty of estimating clean-up costs and compliance, and the possibility that changes will be made to the current environmental laws and regulations. There is also uncertainty in quantifying liabilities under environmental laws that impose joint and several liability on all potentially responsible parties.


Capped electric rates in Virginia may be insufficient to allow full recovery of stranded and other costs.
    Under the Virginia Electric Utility Restructuring Act (the Virginia Restructuring Act), Dominion's electric base rates (excluding, generally, fuel costs and certain other allowable adjustments) remain unchanged until July 2007 unless modified or terminated consistent with that Act. The capped rates and wires charges that, where applicable, are being assessed to customers opting for alternative suppliers allow Dominion to recover certain generation-related costs; however, Dominion remains exposed to numerous risks of cost-recovery shortfalls. These include exposure to potentially stranded costs, future environmental compliance requirements, changes in tax laws, inflation and increased capital costs. See Management's Discussion and Analysis of Financial Condition and Results of Operations-Future Issues and Outlook-Regulated Electric Operations in Dominion's Annu al Report on Form 10-K for the year ended December 31, 2002 and Note 27 to the Consolidated Financial Statements for the year ended December 31, 2002.


The electric generation business is subject to competition.    The generation portion of Dominion's electric utility operations in Virginia is open to competition and is no longer subject to cost-based rate regulation. As a result, there is increased pressure to lower costs, including the cost of purchased electricity. Because Dominion's electric utility generation business has not previously operated in a competitive environment, the extent and timing of entry by additional competitors into the electric market in Virginia is unknown. Therefore, it is difficult to predict the extent to which Dominion will be able to operate profitably within this new environment. In addition, the success of Dominion's merchant power plants depends upon its ability to find buyers willing to enter into power purchase agreements at prices sufficient to cover its operating costs. Depressed spot and forward wholesale power prices and excess capacity could result in lower than expecte d revenues in Dominion's merchant power business.


There are inherent risks in the operation of nuclear facilities
.
    Dominion operates nuclear facilities that are subject to inherent risks. These risks include the cost of and Dominion's ability to maintain adequate reserves for decommissioning, plant maintenance costs, terrorism, spent nuclear fuel disposal costs and exposure to potential liabilities arising out of the operation of these facilities. Dominion maintains decommissioning trusts and external insurance coverage to minimize the financial exposure to these risks. However, it is possible that costs arising from claims could exceed the amount of any insurance coverage.


The use of derivative instruments could result in financial losses.
    Dominion uses derivative instruments, including futures, forwards, options and swaps, to manage its commodity and financial market risks. In addition, Dominion purchases and sells commodity-based contracts in the natural gas, electricity and oil markets for trading purposes. In the future, Dominion could recognize financial losses on these contracts as a result of volatility in the market values of the underlying commodities or if a counterparty fails to perform under a contract. In the absence of actively quoted market prices and pricing information from external sources, the valuation of these contracts involves management's judgment or use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the value of the reported fair value of these contracts. For additional information concerning derivatives and commodity-based trading contracts, see Ma nagement's Discussion and Analysis of Financial Condition and Results of Operations-Market Rate Sensitive Instruments and Risk Management in Dominion's Annual Report on Form 10-K for the year ended December 31, 2002 and Notes 2 and 15 to the Consolidated Financial Statements for the year ended December 31, 2002.

PAGE 24

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Dominion is exposed to market risks beyond its control in its energy clearinghouse operations.    Dominion's energy clearinghouse and risk management operations are subject to multiple market risks including market liquidity, counterparty credit strength and price volatility. Many industry participants have experienced severe business downturns resulting in some being forced to exit or curtail their participation in the energy trading markets. This has led to a reduction in the number of trading partners and lower industry trading revenues. Declining creditworthiness of some of Dominion's trading counterparties may limit the level of its trading activities with these parties and increase the risk that these parties may not perform under a contract.


Successfully executing Dominion's exit from the telecommunications business is dependent upon market conditions and timing.    
In September 2003, Dominion announced it would recognize impairment charges related to DTI, its telecommunications investment, and that it plans to exit the telecommunications business. Dominion expects to formalize its plan of sale during the fourth quarter of 2003. Continued depressed market conditions in the telecommunications industry may make it difficult for Dominion to sell the business as a whole, resulting in sales of telecommunications assets that may not include a transfer of all associated liabilities. Additionally, the difficulty in finding suitable buyers for the telecommunications business and in obtaining required state and federal regulatory approvals could delay the sale of the business. If Dominion fails to sell its telecommunications business quickly, DTI risks the loss of current customers and key employees. DTI requires external sourc es of liquidity for its operating funds. Dominion has advanced, and anticipates making additional advances of, operating funds to DTI. Given its current financial and operating position, it is unlikely that DTI would be able to secure funds from other sources, so it is dependent on continued funding from Dominion to sustain its operations. Any additional funds provided by Dominion may not be recovered from a sale of the telecommunications business. Until a sale occurs, Dominion's investment in the telecommunications business may continue to be adversely affected and could be subject to further impairment charges.


Dominion's exploration and production business is dependent on factors including commodity prices that cannot
be predicted or controlled.    Dominion's exploration and production business is subject to risks beyond its control. These factors include fluctuations in natural gas and crude oil prices, results of future drilling and well completion activities, Dominion's ability to acquire additional land positions in competitive lease areas as well as inherent operational risks that could disrupt production. In addition, in connection with the use of financial derivatives to hedge future sales of gas and oil production, Dominion's liquidity may sometimes be affected by margin requirements. Under these requirements, Dominion must deposit funds with counterparties to cover the fair value of covered contracts in excess of agreed-upon credit limits. Some of these factors could have compounding effects that could also affect Dominion's financial results. Also, because Domini on follows the full cost method of accounting for gas and oil exploration and production activities prescribed by the SEC, short-term market declines in the prices of natural gas and oil could adversely affect its financial results. Under the full cost method, all direct costs of property acquisition, exploration and development activities are capitalized. The principal limitation is that these capitalized amounts may not exceed the present value of estimated future net revenues based on hedge-adjusted period-end prices from the production of proved gas and oil reserves (the ceiling test). If net capitalized costs exceed the ceiling test, in a given country, at the end of any quarterly period, then a permanent write-down of the assets must be recognized in that period.


An inability to access financial markets could affect the execution of Dominion's business plan.
    Dominion relies on access to both short-term money markets and longer-term capital markets as a significant source of liquidity for capital requirements not satisfied by the cash flows from its operations. Management believes that Dominion and its subsidiaries will maintain sufficient access to these financial markets based upon current credit ratings. However, certain disruptions outside of Dominion's control may increase its cost of borrowing or restrict its ability to access one or more financial markets. Such disruptions could include an economic downturn, the bankruptcy of an unrelated energy company or changes to Dominion's credit ratings. Restrictions on Dominion's ability to access financial markets may affect its ability to execute its business plan as scheduled.

PAGE 25

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Changing rating agency requirements could negatively affect Dominion's growth and business strategy.
    As of November 3, 2003, Dominion's senior unsecured debt was rated BBB+, stable outlook, by Standard & Poor's and Baa1, stable outlook, by Moody's. Both agencies have recently implemented more stringent applications of the financial requirements for various ratings levels. In order to maintain its current credit ratings in light of these or future new requirements, Dominion may find it necessary to take steps or change its business plans in ways that may adversely affect its growth and earnings per share. A reduction in Dominion's credit ratings by either Standard & Poor's or Moody's could increase its borrowing costs and adversely affect operating results.


Potential changes in accounting practices may adversely affect Dominion's financial results.
    Dominion cannot predict the impact future changes in accounting standards or practices may have on public companies in general or the energy industry or its operations specifically. New accounting standards could be issued by FASB or the SEC that could change the way Dominion records revenues, expenses, assets and liabilities. These changes in accounting standards could adversely affect Dominion's reported earnings or could increase reported liabilities.

Operating Segments


In general, management's discussion of Dominion's results of operations focuses on the contributions of its operating segments. However, the discussion of Dominion's financial condition under Liquidity and Capital Resources is based on legal entities as Dominion transacts business in the financial markets on that basis. Dominion's three primary operating segments are Dominion Energy, Dominion Delivery and Dominion Exploration & Production. In addition, Dominion also presents its corporate, financial services and other operations as a segment. Amounts for Dominion Energy and Dominion Delivery for 2002 have been restated to reflect Dominion Energy's management of electric transmission operations effective January 1, 2003.


Critical Accounting Policies


As of September 30, 2003, other than the adoption of SFAS No. 143, there have been no significant changes with regard to the critical accounting policies disclosed in MD&A in Dominion's Annual Report on Form 10-K for the year ended December 31, 2002. The policies disclosed included the accounting for: risk management and energy trading contracts at fair value; gas and oil operations; impairment testing; retained interests from securitizations; and regulated operations.


Asset Retirement Obligations

Effective January 1, 2003, Dominion adopted SFAS No. 143, which provides accounting requirements for the recognition and measurement of liabilities associated with the retirement of tangible long-lived assets. At September 30, 2003, Dominion's asset retirement obligations totaled $1.6 billion, the majority of which relates to the decommissioning of its nuclear units.


Asset retirement obligations are recognized at fair value, as incurred, and capitalized as part of the cost of the related tangible long-lived assets. In the absence of quoted market prices, Dominion estimates the fair value of asset retirement obligations using present value techniques, involving discounted cash flow analysis. Measurement using such techniques is dependent upon many subjective factors, including the selection of discount and cost escalation rates, identification of planned retirement activities and related cost estimates and assertions of probability regarding the timing, nature and costs of such activities. Inputs and assumptions are based on the best information available at the time the estimates are made. However, estimates of future cash flows are highly uncertain by nature and may vary significantly from actual results.

PAGE 26

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Results Of Operations


Dominion's discussion of its results of operations includes a tabular summary of contributions by its operating segments to net income and diluted earnings per share (EPS), an overview of consolidated 2003 results of operations, as well as a more detailed discussion of the operating segment results of operations. All variances are stated as actual results for the three and nine months ended September 30, 2003, as compared to the actual results for the same periods of 2002.

 

Net Income (Loss)

Diluted EPS

Three Months Ended September 30,

2003 

2002 

2003 

2002 

 

(millions, except per share amounts)

  Dominion Energy

$296 

$297 

$0.91 

$1.06 

  Dominion Delivery

80 

87 

0.25 

0.31 

  Dominion Exploration & Production

      98 

    90 

   0.30 

  0.32 

    Net income contribution - primary segments

   474 

  474 

   1.47 

  1.69 

  Corporate and Other

  (730)

  (44)

  (2.25)

(0.15)

    Consolidated net income (loss)/EPS

$(256)

$430 

$(0.79)

$1.54 

 

 

 

 

 

Nine Months Ended September 30,

 

 

 

 

  Dominion Energy

$747 

$641 

$2.36 

$2.32 

  Dominion Delivery

291 

274 

0.92 

0.99 

  Dominion Exploration & Production

   299 

    271 

   0.94 

  0.98 

    Net income contribution - primary segments

1,337 

 1,186 

   4.22 

  4.29 

  Corporate and Other

  (845)

  (162)

 (2.66)

(0.58)

    Consolidated net income/EPS

$ 492 

$1,024 

$1.56 

$3.71 


Consolidated Overview - Third Quarter 2003

Dominion recognized a net loss of $0.79 per diluted share on a net loss of $256 million for the third quarter of 2003, a decrease of $686 million and $2.33 per diluted share compared to net income and earnings per share recognized in 2002. This decrease reflects higher net expenses for Corporate and Other, which primarily includes the impairment of telecommunications assets and storm restoration expenses associated with damage caused by Hurricane Isabel.


Dominion's total operating revenue increased (12 percent), primarily reflecting higher gas prices and increased sales volumes by merchant generation fleet and retail sales, partially offset by milder weather and lost electric base rate revenue due to outages caused by Hurricane Isabel.


Total operating expenses increased (58 percent), primarily reflecting the impairment of telecommunications assets and incremental restoration expenses associated with damage caused by Hurricane Isabel. In addition, purchased gas expense increased in connection with higher sales volumes and prices for field services and retail sales operations as well as increased gas prices for regulated gas distribution operations.


The decrease in interest and related charges primarily included the impact of comparably lower interest rates in 2003 and a reduction in interest accrued, resulting from the favorable resolution of previously outstanding income tax issues.


Dominion's effective tax rate increased (15 percent) for the third quarter of 2003. Dominion did not recognize any deferred tax benefits related to the impairment of telecommunications assets, since realization of tax benefits will be dependent upon Dominion's future tax profile and taxable earnings. Dominion's effective tax rate also increased as a result of changes in the valuation allowance on certain deferred tax assets, higher state income taxes and the expiration of nonconventional fuel credits as of January 1, 2003.

PAGE 27

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Consolidated Overview - Nine Months Ended September 30, 2003

Dominion earned $1.56 per diluted share on net income of $492 million for the nine months ended September 30, 2003, a decrease of $532 million and $2.15 per diluted share compared to 2002. The decrease includes net expenses for Corporate and Other, partially offset by higher net income contributions by all operating segments. Net expenses of Corporate and Other for 2003 increased as a result of the impairment of telecommunications assets and certain other costs related to DFV. In addition, net expenses for 2003 also include the impairment of certain other assets held-for-sale, costs associated with workforce reductions, offset by a net gain recognized as the cumulative effect of adopting new accounting standards in 2003. Per share amounts also reflect approximately $0.22 of share dilution, resulting from a substantial increase in the number of shares outstanding during 2003, as compared to 2002.

Total operating revenue increased (21 percent), reflecting the impact of colder weather during the first quarter of 2003, customer growth and higher gas and oil prices.


Total operating expenses increased (38 percent), reflecting the impairment of telecommunications assets; higher purchased gas expense associated with field services, retail sales and regulated gas distribution operations; and higher other operations and maintenance expenses due to storm restoration costs associated with Hurricane Isabel.


Dominion recognized other expenses for the nine months ended September 30, 2003, as compared to other income for the same period in 2002. The other expenses in 2003 primarily reflected certain costs associated with Dominion's telecommunications investment and realized net losses on decommissioning trust investments.

Dominion's effective tax rate increased (6 percent) for the nine months ended September 30, 2003 as a result of the same factors discussed for the third quarter of 2003.

Adoption of EITF 02-3

Effective January 1, 2003, Dominion adopted EITF 02-3. The implementation of EITF 02-3 primarily affects the timing of recognition in earnings for certain Clearinghouse energy-related contracts, as well as the presentation of gains and losses associated with energy-related contracts on the Consolidated Statement of Income.


The adoption of EITF 02-3 had the following initial and ongoing impact on the accounting for and presentation of Clearinghouse energy-related contracts in the Consolidated Financial Statements, effective January 1, 2003:


The recognition and presentation requirements of EITF 02-3 described above were applied prospectively in 2003, and the Consolidated Statements of Income for the three and nine months ended September 30, 2002 were not restated.

 

PAGE 28

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Dominion Energy


Three Months Ended September 30,

Nine Months Ended September 30,

Selected Financial and Statistical Information

2003

2002

2003

2002

 

 

(millions, except per share amounts)

 

Selected operating revenue:

 

 

 

 

 

  Regulated electric sales

$1,078

$1,152

$2,922

$2,964

 

  Nonregulated electric sales

311

266

900

741

 

  Nonregulated gas sales

328

110

1,307

491

 

  Other revenue

99

35

289

102

 

Selected operating expenses:

 

 

 

 

 

  Electric fuel and energy purchases, net

$444

$418

$1,214

$1,080

 

  Purchased electric capacity

152

173

463

517

 

  Purchased gas

309

101

1,093

486

 

  Liquids, pipeline capacity and other purchases

72

4

197

10

 

  Other operations and maintenance

315

304

1,019

901

 

  Depreciation

85

97

246

300

 

Other income

45

37

30

56

 

Net income contribution

296

297

747

641

 

Diluted EPS contribution

$0.91

$1.06

$2.36

$2.32

 

Electricity supplied* (million mwhrs)

29

29

81

76

 

Gas transmission throughput (bcf)

78

105

426

416

 

________________

* Amounts presented are for electricity supplied by utility and merchant energy operations.


Operating Results - Third Quarter 2003


Dominion Energy contributed $0.91 per diluted share on net income of $296 million for the third quarter of 2003, a net income decrease of $1 million and an earnings per share decrease of $0.15 compared to 2002. Share dilution reduced Dominion Energy's contribution to diluted earnings per share by approximately $0.14 per share.


The overall increase in operating revenue primarily reflected the following:

PAGE 29

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


The overall increase in operating expenses primarily reflected the following:

Operating Results - Nine Months Ended September 30, 2003

Dominion Energy contributed $2.36 per diluted share on net income of $747 million for the nine months ended September 30, 2003, a net income increase of $106 million and an earnings per share increase of $0.04 over 2002. Share dilution reduced Dominion Energy's contribution to diluted earnings per share by approximately $0.35 per share.


The overall increase in operating revenue primarily reflected the following:

 

PAGE 30

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


The overall increase in operating expenses primarily reflected the following:


The decrease in other income reflects net realized losses on investments held in Dominion's decommissioning trusts.

Selected Information-Energy Trading Activities


See Selected Information-Energy Trading Activities in the reformatted portion of MD&A included in the current report on Form 8-K filed on May 9, 2003 for a detailed discussion of the energy trading, hedging and arbitrage activities of the Clearinghouse and related accounting policies. For additional discussion of trading activities, see Market Rate Sensitive Instruments and Risk Management.


The Clearinghouse holds a portfolio of financial derivative instruments used by Dominion to manage the price risk of certain anticipated sales of Dominion Exploration & Production's 2003 natural gas production (economic hedges). At December 31, 2002, these financial derivative instruments had not been designated as hedges for accounting purposes. During the first quarter of 2003, Dominion designated a portion of these financial derivative instruments as cash flow hedges for accounting purposes. Therefore, beginning on the designation date, changes in fair value for these derivatives, or the portion thereof, that represent an "effective" hedge for accounting purposes will be recorded in accumulated other comprehensive income rather than directly to earnings. Such amounts are reclassified to earnings during periods in which the hedged transactions affect earnings. Dominion's earnings for 2003 reflect the changes in fair value of the financial derivative instruments prior to being designated as cash flow hedges, and changes in fair value of the remaining instruments that continue to be held as economic hedges through September 30, 2003. For the three and nine months ended September 30, 2003, Dominion Energy recognized a net gain of $14 million and a net loss of $18 million, respectively, on the economic hedges.

PAGE 31

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


During the remainder of 2003, individual quarterly earnings reflect unrealized changes in the fair value of those instruments that held as economic hedges, including financial settlements of such instruments, as well as the anticipated gas sales at then current market prices. For the entirety of 2003, Dominion expects the combination of the anticipated gas sales by Dominion Exploration & Production and the economic hedges to result in a range of prices for those sales as contemplated by its risk management strategy.


A summary of the changes in the unrealized gains and losses recognized for Dominion's energy-related derivative instruments held for trading purposes, including the economic hedges described above, during the nine months ended September 30, 2003 follows:

 

 


Amount

 

 

(millions)

 

Net unrealized gain at December 31, 2002

$170 

 

  Reclassification of contracts - adoption of EITF 02-3:

 

 

    Non-derivative energy contracts

(110)

 

    Derivative energy contracts, not held for trading purposes

 (81)

 

 

(21)

 

  Contracts realized or otherwise settled during the period

42 

 

  Net unrealized gain at inception of contracts initiated during the period

-- 

 

  Changes in valuation techniques

-- 

 

  Other changes in fair value

  52 

 

Net unrealized gain at September 30, 2003

$73 

 

The balance of net unrealized gains and losses recognized for Dominion's energy-related derivative instruments held for trading purposes, including the economic hedges discussed above, at September 30, 2003 is summarized in the following table based on the approach used to determine fair value and the contract settlement or delivery dates:

 

Maturity Based on Contract Settlement or Delivery Date(s)

 



Source of Fair Value


Less than
1 year


1-2
years


2-3
years


3-5
years

In Excess
of
5 years



Total

 

 

(millions)

 

Actively quoted (1)

$16

$29

$8

--

--

$53

 

Other external sources (2)

--

11

7

$2

--

20

 

Models and other valuation methods (3)

  --

  --

  --

 --

 --

  --

 

    Total

$16

$40

$15

$2

 --

$73

 

(1)  Exchange-traded and over-the-counter contracts.

(2)  Values based on prices from over-the-counter broker activity and industry services and, where applicable, conventional option pricing models.

(3)  Values based on Dominion's estimate of future commodity prices when information from external sources is not available and use of internally-developed models, reflecting option pricing theory, discounted cash flow concepts, etc.

 

PAGE 32

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Dominion Delivery

 

Three Months Ended September 30,

Nine Months Ended September 30,

 

2003

2002

2003

2002

 

 

(millions, except per share amounts)

 

Selected operating revenue:

 

 

 

 

 

  Regulated electric sales

$305

$302

$820

$767

 

  Regulated gas sales

121

82

851

542

 

Selected operating expenses:

 

 

 

 

 

  Purchased gas, net

78

40

609

330

 

  Other operations and maintenance

147

135

442

410

 

  Depreciation

86

72

254

225

 

  Other taxes

34

33

142

122

 

Other income (loss)

6

(2)

14

2

 

Net income contribution

80

87

291

274

 

Diluted EPS contribution

$0.25

$0.31

$0.92

$0.99

 

Electricity delivered (million mwhrs)

21

22

58

57

 

Gas throughput (bcf)

41

43

266

244

 

Operating Results - Third Quarter 2003

Dominion Delivery contributed $0.25 per diluted share on net income of $80 million for the third quarter of 2003, a net income decrease of $7 million and an earnings per share decrease of $0.06 compared to 2002. Share dilution reduced Dominion Delivery's contribution to diluted earnings per share by approximately $0.04 per share. Incremental restoration expenses associated with damage caused by Hurricane Isabel are reported in Corporate and Other.


The overall increase in operating revenue primarily reflected the following:


The overall increase in operating expenses primarily reflected the following:


The increase in other income reflects equity losses recorded in 2002 when DFV was accounted for under the equity method. Dominion began consolidating DFV during the first quarter of 2003.

PAGE 33

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Operating Results - Nine Months Ended September 30, 2003


Dominion Delivery contributed $0.92 per diluted share on net income of $291 million for the nine months ended September 30, 2003, a net income increase of $17 million and an earnings per share decrease of $0.07 compared to 2002. Share dilution reduced Dominion Delivery's contribution to diluted earnings per share by approximately $0.13 per share.


The overall increase in operating revenue primarily reflected the following:


The overall increase in operating expenses primarily reflected the following:


The increase in other income reflects equity losses recorded in 2002 when DFV was accounted for under the equity method. Dominion began consolidating DFV during the first quarter of 2003.

 

PAGE 34

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Dominion Exploration & Production

 

Three Months Ended September 30,

Nine Months Ended September 30,

Selected Financial and Statistical Information

2003

2002

2003

2002

 

 

(millions, except per share amounts and average prices)

 

Selected operating revenue:

 

 

 

 

 

  Gas and oil production revenue

$413

$353

$1,256

$1,035

 

  Other revenue

59

58

188

162

 

Selected operating expenses:

 

 

 

 

 

  Purchased gas

29

17

97

59

 

  Other operations and maintenance

94

83

295

237

 

  Depreciation, depletion and amortization

137

130

398

380

 

  Other taxes

23

12

73

41

 

Other income (loss)

(5)

2

3

23

Effective tax rate

37%

29%

37%

30%

Net income contribution

$98

$90

$299

$271

Diluted EPS contribution

$0.30

$0.32

$0.94

$0.98

 

Average realized prices with hedging results(1)

 

 

 

 

 

  Gas (per mcf)(2)

$3.89

$3.38

$4.01

$3.33

 

  Oil (per bbl)

$23.90

$24.15

$24.66

$22.96

 

Average prices without hedging results

 

 

 

 

 

  Gas (per mcf)(2)

$4.65

$2.93

$5.19

$2.80

 

  Oil (per bbl)

$29.00

$26.24

$29.92

$23.88

 

Gas production (bcf)

96.7

96.8

289.0

285.3

 

Oil production (million bbls)

2.2

2.4

6.7

7.3

 

_______________

(1)  Excludes the effects of the "economic hedges" and cash flow hedges discussed in the operating results of Dominion Energy under Selected Information-Energy Trading Activities. Dominion's consolidated average prices, including the effects of the cash flow hedges, were not materially different from those prices reported in this table.

(2)  Excludes $14 million of revenue recognized for the three and nine months ended September 30, 2003 under the volumetric production payment agreement described in Note 18 to the Consolidated Financial Statements.


Operating Results - Third Quarter and Nine Months Ended September 30, 2003

Dominion Exploration & Production contributed $0.30 per diluted share on net income of $98 million for the third quarter of 2003, a net income increase of $8 million and an earnings per share decrease of $0.02 compared to 2002. Share dilution reduced Dominion Exploration & Production's contribution to diluted earnings per share by approximately $0.05 per share.


Dominion Exploration & Production contributed $0.94 per diluted share on net income of $299 million for the nine months ended September 30, 2003, a net income increase of $28 million and an earnings per share decrease of $0.04 compared to 2002. Share dilution reduced Dominion Exploration & Production's contribution to diluted earnings per share by approximately $0.14 per share.


Operating revenue from gas and oil production increased for the third quarter of 2003, primarily due to higher average realized prices for gas.


Operating revenue also increased for the nine months ended September 30, 2003, primarily due to higher average realized prices for gas and oil, as well as higher gas production volumes. In addition, other revenues increased as a result of realized prices for extracted by-products and brokered oil sales.

PAGE 35

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


The overall increase in operating expenses for both the third quarter and nine months ended September 30, 2003, primarily reflected the following:

The effective tax rate increased primarily as a result of the expiration of nonconventional fuel tax credits, beginning in 2003.


Other income for the nine months ended September 30, 2003 decreased, reflecting a $10 million gain on the sale of an investment in 2002 and an $8 million increase in foreign currency translation losses in 2003 associated with Canadian operations.

Corporate and Other

 

Three Months Ended September 30,

Nine Months Ended September 30,

 

2003

2002

2003

2002

 

 

(millions, except per share amounts)

 

Net expense

$(730)

$(44)

$(845)

$(162)

 

Diluted EPS impact

$(2.25)

$(0.15)

$(2.66)

$(0.58)

 

Operating Results - Third Quarter 2003

Net expense associated with corporate and other operations for the third quarter of 2003 was $730 million and $(2.25) per diluted share, an increase in net expense of $686 million and $(2.10) per diluted share as compared to 2002. The increase in net expense primarily reflects the following specific items:

PAGE 36

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Operating Results - Nine Months Ended September 30, 2003

Net expense associated with corporate and other operations for the nine months ended September 30, 2003 was $845 million and $(2.66) per diluted share, an increase in net expense of $683 million and $2.08 per diluted share as compared to 2002. The increase in net expense primarily reflects the following specific items:


Liquidity and Capital Resources


Dominion and its subsidiaries depend on both internal and external sources of liquidity to provide working capital and to fund capital requirements. Short-term cash requirements not met by the cash flow from operations are generally satisfied with proceeds from short-term borrowings. Long-term cash needs are met through sales of securities and long-term debt financings.


Internal Sources of Liquidity


As presented on Dominion's Consolidated Statements of Cash Flows, net cash flows from operating activities were $2.1 billion and $1.9 billion for the nine months ended September 30, 2003 and 2002, respectively. Dominion's management believes that its operations provide a stable source of cash flow sufficient to contribute to planned levels of capital expenditures and maintain current shareholder dividend levels. As noted above, Dominion uses a combination of debt and equity securities to fund capital requirements not covered by the timing or amounts of operating cash flows. As discussed under Credit Ratings and Cash Requirements for Planned Capital Expenditures in the MD&A of Dominion's Annual Report on Form 10-K for the year ended December 31, 2002, Dominion is taking steps to improve its financial position in response to current credit rating requirements. As a result of these measures, Dominion may choose to postpone or cancel certain planned capital expenditures, to the extent they are not fully covered by operating cash flows.

PAGE 37

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Dominion's operations are subject to risks and uncertainties that may negatively impact cash flows from operations. See the discussion of such factors in Internal Sources of Liquidity in the MD&A of Dominion's Annual Report on Form 10-K for the year ended December 31, 2002.

External Sources of Liquidity


In the External Sources of Liquidity section of MD&A in Dominion's Annual Report on Form 10-K for the year ended December 31, 2002, Dominion discussed the use of capital markets by Dominion Resources, Inc., Virginia Electric and Power Company (Virginia Power), and Consolidated Natural Gas Company (CNG), collectively the Dominion Companies, as well as the impact of credit ratings on the accessibility and costs of using these markets. In addition, that section of MD&A discussed various covenants present in the enabling agreements underlying the Dominion Companies' debt. As of September 30, 2003, there have been no changes in the Dominion Companies' credit ratings and no changes to or events of default under Dominion's debt covenants. In October 2003, Moody's upgraded its outlook for Dominion Resources, Inc. from negative to stable.


During the nine months ended September 30, 2003, Dominion and its subsidiaries issued long-term debt (net of exchanged debt) and common stock totaling approximately $3.2 billion. The proceeds were used primarily to acquire the DFV senior notes, repay other debt and finance capital expenditures.


Credit Facilities and Short-Term Debt

The Dominion Companies use short-term debt, primarily commercial paper, to fund working capital requirements and as bridge financing for acquisitions. The levels of borrowing may vary significantly during the course of the year, depending upon the timing and amount of cash requirements not satisfied by cash from operations. The commercial paper programs are supported by various credit facilities as discussed below. At September 30, 2003, the Dominion Companies had the following short-term debt outstanding and capacity available under credit facilities:



Facility Limit

Outstanding Commercial Paper

Outstanding Letters of Credit

Facility Capacity Available

(millions)

364-day joint revolving credit facility

$1,250

Three-year joint revolving credit facility

    750

  Total joint credit facilities(1)

2,000

$875

$88

$1,037

364-day CNG credit facility(2)

  1,000

     --

  586

     414

     Totals

$3,000

$875

$674

$1,451

__________________________

(1) The joint credit facilities support borrowings by the Dominion Companies. The 364-day revolving credit facility was executed in May 2003 and terminates in May 2004. The three-year revolving credit facility was executed in May 2002 and terminates in May 2005.

(2) The credit facility is used to support the issuance of letters of credit and commercial paper by CNG to fund collateral requirements under its gas and oil hedging program. The facility was executed in August 2003 and terminates in August 2004.

PAGE 38

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Long-Term Debt

During the nine months ended September 30, 2003, Dominion Resources, Inc. and its subsidiaries issued the following long-term debt:

Type

Principal

Rate

Maturity

Issuing Company

 

(millions)

 

 

 

Senior notes

$1,810 

2.80% to 6.30%

2005 to 2033

Dominion Resources, Inc.

Senior notes

500 

Variable

2013

Dominion Resources, Inc.

Senior notes

     400 

4.75%

2013

Virginia Power

  Total long-term debt issued

$2,710 

 

 

 

  Less: direct exchange(1)

   (500)

 

 

 

Total long-term debt issued, excluding direct exchanges


$2,210
 

 

 

 

____________________

(1) During the third quarter of 2003, Dominion redeemed its $500 million variable rate senior notes due 2013. In a direct exchange, Dominion completed the redemption by issuing $510 million of 5.25 percent senior notes due 2033.


In addition to the senior notes described above, during the third quarter, Dominion borrowed $18 million to complete a power generation project at Virginia Power's Possum Point power station.


During the nine months ended September 30, 2003, Dominion Resources, Inc. and its subsidiaries repaid $2.0 billion of long-term debt securities. Dominion used the entirety of its $500 million escrow deposit, established in December 2002, to repay matured debt in January 2003.


Issuance of Common Stock

During the nine months ended September 30, 2003, Dominion received proceeds of $253 million through Dominion Direct (a dividend reinvestment and open enrollment direct stock purchase plan), employee savings plans and the exercise of employee stock options. In addition, during the second quarter of 2003, Dominion received proceeds of $683 million through a public equity offering.


Amounts Available under Shelf Registrations

At September 30, 2003, Dominion Resources, Inc., Virginia Power, and CNG had approximately $3.0 billion, $1.3 billion, and $1.5 billion, respectively, of available capacity under currently effective shelf registrations. Securities that may be issued under these shelf registrations, depending upon the registrant, include senior notes (including medium-term notes), subordinated notes, first and refunding mortgage bonds, trust preferred securities, preferred stock and common stock.


Investing Activities


During the nine months ended September 30, 2003, investing activities resulted in a net cash outflow of $2.5 billion, reflecting the following primary investing activities:


partially offset by:

PAGE 39

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Off-Balance Sheet Arrangements


Leases with Special Purpose Entities

Dominion, through certain subsidiaries, has entered into agreements with VIEs in order to finance and lease several new power generation projects, as well as its corporate headquarters and aircraft. Neither the project assets nor the related obligations are currently reported on Dominion's Consolidated Balance Sheets under existing accounting guidance.


Dominion estimates that consolidating those VIEs for which it is the primary beneficiary under FIN 46, effective December 31, 2003, will result in an additional $647 million in net property, plant and equipment and $688 million of related debt. The cumulative effect of adopting FIN 46 is estimated to result in an after-tax charge of $25 million, representing depreciation expense associated with the consolidated assets. Annual depreciation expense for these assets is expected to total $20 million.


During the second quarter of 2003, for one of the power generation projects under construction, Dominion entered into a new arrangement with a non-affiliated voting interest entity. The voting interest entity will not be consolidated by Dominion under FIN 46. Project costs totaled $626 million at September 30, 2003 for this project, of which $560 million was advanced by Dominion. This project is expected to be completed in 2004 and will result in estimated annual lease commitments of approximately $58 million.


Cash Requirements for Planned Capital Expenditures


The timing for reimbursement of amounts advanced by Dominion in connection with a generation project to be leased by Dominion upon completion has changed. As a result, amounts previously disclosed in MD&A in Dominion's Annual Report on Form 10-K for the year ended December 31, 2002 for cash requirements for planned capital expenditures for 2003 will increase, and amounts for 2004 will decrease, by approximately $700 million.


Contractual Obligations


As of September 30, 2003, other than scheduled maturities of new debt issued during the nine months ended September 30, 2003 and increased fuel commitments described in Note 14 to the Consolidated Financial Statements, there have been no significant changes to the contractual obligations disclosed in MD&A in Dominion's Annual Report on Form 10-K for the year ended December 31, 2002.


Future Issues


The following discussion of future issues and other information includes current developments of previously disclosed matters and new issues arising during the period covered by and subsequent to the Consolidated Financial Statements. This section should be read in conjunction with Future Issues and Outlook in MD&A in Dominion's Annual Report on Form 10-K for the year ended December 31, 2002.


Regulated Electric Operations


Regional Transmission Organization (RTO)

In June 2003, Dominion submitted an application to the Virginia State Corporation Commission (Virginia Commission), as required by the Virginia Restructuring Act, requesting authorization to become a transmission owning member of PJM Interconnection, LLC (PJM) and transfer operational control of Dominion's electric transmission facilities to PJM on November 1, 2004. The Virginia Commission issued an order in September 2003 that directed Dominion to provide additional information concerning its application and stated that it will not fully consider the application and make a final determination until the Federal Energy Regulatory Commission (FERC) has issued a final order addressing Standard Market Design. It is uncertain at this time when FERC will issue a final order on Standard Market Design. Dominion has requested that the Virginia Commission eliminate the requirement to provide the additional information and establish a schedule to rule on its application without a FERC final o rder on Standard Market Design.

 

PAGE 40

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)


Virginia Rate Matters

In July 2003, Dominion filed its 2004 fuel factor application with the Virginia Commission, requesting a total fuel factor increase of $442 million that included a projected $308 million under-recovery balance as of December 31, 2003. The under-recovery balance was attributed to nuclear plant outages for reactor vessel head replacements, increased fuel prices and an unusually cold winter. Dominion also suggested for consideration a cost recovery mechanism that would amortize the under-recovery balance over two years.

In October 2003, Dominion reached a tentative settlement of its 2004 fuel factor application with the Virginia Attorney General's Office, the Virginia Commission Staff and other parties. If approved by the Virginia Commission, the settlement would reduce the total proposed increase by $56 million to $386 million. The reduction includes $42 million attributed to updated projected fuel cost forecasts and the recognition of $14 million of previously deferred fuel costs which would now not be recovered. The settlement includes a recovery period for the under-recovery balance over three and a half years. About $171 million of the $386 million would be recovered in 2004, $85 million in 2005, $87 million in 2006 and $43 million in the first six months of 2007. The proposed settlement addressed neither the extent to which Dominion's trading activities may be taken into account by the Virginia Commission in future fuel factor determinations nor a party's recommended delay in the effective date of i ncreased fuel rates to allow the General Assembly an opportunity to consider issues raised in this fuel factor proceeding.

Dominion is still permitted under the Virginia Restructuring Act to request adjustments to its fuel rates until July 1, 2007.

Status of Retail Competition in Virginia

In August 2003, the Virginia Commission issued its third annual report on the status of the development of a competitive retail market for electric generation in Virginia. In the report, the Virginia Commission renewed its recommendation that the General Assembly suspend key portions of the Virginia Restructuring Act through the re-bundling of retail rates and suspension of the Act's retail choice provisions. The report also recommended extending the moratorium on Virginia utilities' participation in RTOs. In October 2003 the offices of the Governor and the Attorney General recommended that the Commission on Electric Utility Restructuring consider legislation that would extend the existing capped rates under the Virginia Restructuring Act for three years, until July 1, 2010, and phase out or eliminate wires charges.

Proposed Pilot Programs

In September 2003, the Virginia Commission issued a final order approving three proposed electric retail access pilot programs, subject to several specified modifications. The pilot programs will run through the remainder of the capped rate period and make available to competitive service providers up to 500 megawatts of load, with expected participation of more than 65,000 customers from a variety of customer classes. Enrollment in the pilot programs is scheduled to begin in February 2004.


Regulated Gas Distribution Operations


Rate Matters

Dominion's gas distribution business subsidiaries are subject to regulation of rates and other aspects of their businesses by the states in which they operate-Pennsylvania, Ohio and West Virginia. When necessary, Dominion's gas distribution subsidiaries seek general rate increases on a timely basis to recover increased operating costs. In addition to general rate increases, certain of Dominion's gas distribution subsidiaries make routine separate filings with their respective state regulatory commissions to reflect changes in the costs of purchased gas. These purchased gas costs are generally subject to rate recovery through a mechanism that ensures dollar for dollar recovery of prudently incurred costs. Costs that are expected to be recovered in future rates are deferred as regulatory assets. The purchased gas cost recovery filings generally cover prospective three-month or twelve-month periods. Approved increases or decreases in gas cost recovery rates result in increases or decr eases in revenues with corresponding increases or decreases in net purchase gas cost expenses.

 

PAGE 41

DOMINION RESOURCES, INC.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Continued)

In August 2003, Dominion filed an application with the West Virginia Public Service Commission (the West Virginia Commission) to increase its purchased gas cost rate by approximately $31 million on an annualized basis, effective for the period January 1, 2004 through October 31, 2004. The increase is in anticipation of higher purchased gas costs expected for that period. Because Dominion's existing rate moratorium will expire at the end of 2003, the application reflects a return to the traditional purchase gas adjustment treatment for Dominion's purchased gas costs. The West Virginia Commission is expected to issue an order setting an interim rate in the fourth quarter of 2003, with a final rate order to be issued in early 2004.

Environmental Matters


In relation to a Notice of Violation received by Virginia Power in 2000 from the EPA and related proceedings, Virginia Power, the U.S. Department of Justice, the EPA, the states of Virginia, West Virginia, Connecticut, New Jersey and New York agreed to a settlement in April 2003 in the form of a proposed Consent Decree. The Virginia federal district court entered the final Consent Decree in October 2003, resolving the underlying actions. The settlement includes payment of a $5 million civil penalty, an obligation to fund $14 million for environmental projects and a commitment to improve air quality under the Consent Decree estimated to involve expenditures of $1.2 billion. Dominion has already incurred certain capital expenditures for environmental improvements at its coal-fired stations in Virginia and West Virginia and has committed to additional measures in its current financial plans and capital budget to satisfy the requirements of the Consent Decree. As of September 30, 2003, Dominion had accrued $19 m illion for the civil penalty and the funding of the environmental projects, substantially all of which was recorded in 2000.


Other


Telecommunications Operations

Dominion expects to formalize the plan of divestiture for DTI and anticipates presenting DTI's assets as held-for-sale and its results of operations as discontinued operations beginning at that time. As part of implementing its plan of sale, Dominion expects to purchase the Investor Trust's interest in DFV for approximately $60 million during the fourth quarter of 2003, resulting in a loss of a similar amount at that time. In addition, DTI has long-term obligations, including leases and maintenance and other contracts, that must be considered in the plan of sale and may result in additional losses in future periods depending upon the final terms of disposition.


Restructuring of Contract with Non-Utility Generating Facility

In July 2003, Dominion reached an agreement, pending regulatory approvals, to pay approximately $150 million for the termination of a long-term power purchase contract and the purchase of the related generating facility used by a non-utility generator to provide electricity to Dominion. Dominion expects the transaction to be completed in the fourth quarter of 2003, resulting in an after-tax charge in the range of $65 million to $85 million for the purchase and termination of the long-term power purchase contract. The transaction is part of an ongoing program which seeks to achieve competitive cost structures at Dominion's power generating business.


Accounting Matters


The following new accounting standards will be adopted during the fourth quarter of 2003, as described in Note 4 to the Consolidated Financial Statements:

PAGE 42

DOMINION RESOURCES, INC.

ITEM 3. QUANTITATIVE AND QUALITATIVE
DISCLOSURES ABOUT MARKET RISK


The matters discussed in this Item may contain "forward-looking statements" as described in the introductory paragraphs under Part I, Item 2, Management's Discussion and Analysis of Financial Condition and Results of Operations of this Form 10-Q. The reader's attention is directed to those paragraphs for discussion of various risks and uncertainties that may affect the future of Dominion.


Market Rate Sensitive Instruments and Risk Management


Dominion's financial instruments, commodity contracts and related derivative financial instruments are exposed to potential losses due to adverse changes in interest rates, equity security prices, foreign currency exchange rates and commodity prices. Interest rate risk generally is related to Dominion's outstanding debt and financial services activities. Commodity price risk is present in Dominion's electric operations, gas production and procurement operations, and energy marketing and trading operations due to the exposure to market shifts in prices received and paid for natural gas, electricity and other commodities. Dominion uses derivative commodity contracts to manage price risk exposures for these operations. In addition, Dominion is exposed to equity price risk through various portfolios of equity securities.


Dominion's sensitivity analysis estimates the potential loss of future earnings or fair value from market risk sensitive instruments over a selected time period due to a 10 percent unfavorable change in commodity prices, interest rates and foreign currency exchange rates.


Commodity Price Risk-Trading Activities

As part of its strategy to market energy and to manage related risks, Dominion manages a portfolio of commodity-based derivative instruments held for trading purposes. These contracts are sensitive to changes in the prices of natural gas, electricity and certain other commodities. Dominion uses established policies and procedures to manage the risks associated with these price fluctuations and uses derivative instruments, such as futures, forwards, swaps and options, to mitigate risk by creating offsetting market positions. In addition, Dominion seeks to use its generation capacity, when not needed to serve customers in its service territory, to satisfy commitments to sell energy.

A hypothetical 10 percent unfavorable change in commodity prices would have resulted in a decrease of approximately $19 million and $12 million in the fair value of Dominion's commodity-based financial derivative instruments held for trading purposes as of September 30, 2003 and December 31, 2002, respectively.


Commodity Price Risk-Non-Trading Activities

Dominion manages the price risk associated with purchases and sales of natural gas, oil and electricity by using derivative commodity instruments including futures, forwards, options and swaps. For sensitivity analysis purposes, the fair value of Dominion's non-trading derivative commodity instruments is determined based on models that consider the market prices of commodities in future periods, the volatility of the market prices in each period, as well as the time value factors of the derivative instruments. Market prices and volatility are principally determined based on quoted prices on the futures exchange. A hypothetical 10 percent unfavorable change in market prices of Dominion's non-trading financial derivative commodity instruments would have resulted in a decrease in fair value of approximately $391 million and $357 million as of September 30, 2003 and December 31, 2002, respectively.


The impact of a change in energy commodity prices on Dominion's non-trading derivative commodity instruments at a point in time is not necessarily representative of the results that will be realized when such contracts are ultimately settled. Net losses from derivative commodity instruments used for hedging purposes, to the extent realized, are generally offset by recognition of the hedged transaction, such as revenue from sales.


Interest Rate Risk

Dominion's interest rate risk exposure does not differ materially from that discussed under Item 7A of its Annual Report on Form 10-K for 2002.


Foreign Exchange Risk

Dominion's foreign exchange risk exposure does not differ materially from that discussed under Item 7A of its Annual Report on Form 10-K for 2002.

PAGE 43

DOMINION RESOURCES, INC.

ITEM 3. QUANTITATIVE AND QUALITATIVE
DISCLOSURES ABOUT MARKET RISK

(Continued)


Investment Price Risk

Dominion is subject to investment price risk due to marketable securities held as investments in decommissioning trust funds. In accordance with current accounting standards, these marketable securities are reported on the Consolidated Balance Sheets at fair value. Dominion recognized a net realized loss (net of investment income) of $21 million and a net unrealized gain of $142 million on decommissioning trust investments for the first nine months of 2003. For the year ended December 31, 2002, Dominion recognized a net realized gain (including investment income) of $32 million and a net unrealized loss of $166 million.

PAGE 44

DOMINION RESOURCES, INC.


ITEM 4. CONTROLS AND PROCEDURES


Senior management, including the Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of Dominion's disclosure controls and procedures as of the end of the period covered by this report. Based on this evaluation process, the Chief Executive Officer and Chief Financial Officer have concluded that Dominion's disclosure controls and procedures are effective. There were no changes in Dominion's internal control over financial reporting that occurred during the last fiscal quarter that have materially affected, or are reasonably likely to materially affect, Dominion's internal control over financial reporting.

PAGE 45

DOMINION RESOURCES, INC.
PART II. - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS


From time to time, Dominion and its subsidiaries are alleged to be in violation or in default under orders, statutes, rules or regulations relating to the environment, compliance plans imposed upon or agreed to by Dominion and its subsidiaries, or permits issued by various local, state and federal agencies for the construction or operation of facilities. From time to time, there also may be administrative proceedings on these matters pending. In addition, in the normal course of business, Dominion and its subsidiaries are involved in various legal proceedings. Management believes that the ultimate resolution of these proceedings will not have a material adverse effect on Dominion's financial position, liquidity or results of operations. See Future Issues in Management's Discussion and Analysis of Financial Condition and Results of Operations (MD&A) for discussion on various regulatory proceedings to which Dominion and its subsidiaries are a party.


In June 2002, Wiley Fisher, Jr. and John Fisher filed a purported class action lawsuit against Virginia Power and Dominion Telecom, Inc. (Dominion Telecom) in the U.S. District Court in Richmond, Virginia. The plaintiffs claim that Virginia Power and Dominion Telecom strung fiber-optic cable across their land, along a Virginia Power electric transmission corridor without paying compensation. The plaintiffs are seeking damages for trespass and "unjust enrichment," as well as punitive damages from the defendants. The named plaintiffs purport to "represent a class . . . consisting of all owners of land in North Carolina and Virginia, other than public streets or highways, that underlies Virginia Power's electric transmission lines and on or in which fiber optic cable has been installed." In August 2003, the federal district court issued an order granting the named plaintiffs' motion for class certification. The U.S. Court of Appeals for the Fourth Circuit denied Dominion's petition for appeal and i ts petition for rehearing on the class certification issue. The outcome of the proceeding, including an estimate as to any potential exposure, cannot be predicted at this time.


In connection with a Notice of Violation received by Virginia Power in 2000 from the U.S. Environmental Protection Agency (EPA) and related proceedings, the Virginia federal district court entered the final Consent Decree in October 2003 involving Dominion, the U.S. government and five states. See Environmental Matters in the MD&A of this Form 10-Q for further information relating to this development.


In l999, a class action was filed by Quinque Operating Co. and other parties against approximately 300 defendants, including CNG and three of its subsidiaries, in Stevens County, Kansas. The complaint seeks damages for alleged fraud, misrepresentation, conversion and assorted other claims in the measurement and payment of gas royalties from privately held gas leases. Quinque Operating Co. dropped out of the case and Will Price, a gas royalty owner based in Kansas, assumed the lead plaintiff's role. The defendants' motion to deny class certification was granted in April 2003. In June 2003, the CNG defendants were dropped from the suit. The deadline to file an amended complaint has expired and this matter is now considered closed.

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

(a) Exhibits:

 

3.1

Articles of Incorporation as in effect August 9, 1999, as amended March 12, 2001 (Exhibit 3.1, Form 10-K for the year ended December 31, 2002, File No. 1-8489, incorporated by reference).

 

3.2

Bylaws as in effect on October 20, 2000 (Exhibit 3, Form 10-Q for the quarter ended September 30, 2000, File No. 1-8489, incorporated by reference).

 

PAGE 46

DOMINION RESOURCES, INC.
PART II. - OTHER INFORMATION


ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

 

4

Form of Senior Indenture, dated June 1, 2000, between Dominion Resources, Inc. and JP Morgan Chase Bank (formerly The Chase Manhattan Bank), as Trustee (Exhibit 4 (iii), Form S-3, Registration Statement, File No. 333-93187, incorporated by reference); First Supplemental Indenture, dated June 1, 2000 (Exhibit 4.2, Form 8-K, dated June 21, 2000, File No. 1-8489, incorporated by reference); Second Supplemental Indenture, dated July 1, 2000 (Exhibit 4.2, Form 8-K, dated July 11, 2000, File No. 1-8489, incorporated by reference); Third Supplemental Indenture, dated July 1, 2000 (Exhibit 4.3, Form 8-K dated July 11, 2000, incorporated by reference); Fourth Supplemental Indenture and Fifth Supplemental Indenture dated September 1, 2000 (Exhibit 4.2, Form 8-K, dated September 8, 2000, incorporated by reference); Sixth Supplemental Indenture, dated September 1, 2000 (Exhibit 4.3, Form 8-K, dated September 8, 2000, incorporated by reference); Seventh Supplemental Indenture, dated Octobe r 1, 2000 (Exhibit 4.2, Form 8-K, dated October 11, 2000, incorporated by reference); Eighth Supplemental Indenture, dated January 1, 2001 (Exhibit 4.2, Form 8-K, dated January 23, 2001, incorporated by reference); Ninth Supplemental Indenture, dated May 1, 2001 (Exhibit 4.4, Form 8-K, dated May 25, 2001, incorporated by reference); Form of Tenth Supplemental Indenture (Exhibit 4.2, Form 8-K filed March 18, 2002, File No. 1-8489, incorporated by reference); Form of Eleventh Supplemental Indenture (Exhibit 4.2, Form 8-K filed June 25, 2002, File No. 1-8489, incorporated by reference.); Form of Twelfth Supplemental Indenture (Exhibit 4.2, Form 8-K filed September 11, 2002, File No. 1-8489, incorporated by reference); Thirteenth Supplemental Indenture dated September 16, 2002 (Exhibit 4.1, Form 8-K filed September 17, 2002, File No. 1-8489, incorporated by reference); Fourteenth Supplemental Indenture, dated August 20, 2003 (Exhibit 4.4, Form 8-K filed August 20, 2003, File No. 1-8489, incorporated by reference ); Forms of Fifteenth and Sixteenth Supplemental Indentures (Exhibits 4.2 and 4.3 to Form 8-K filed December 12, 2002, File No. 1-8489, incorporated by reference); Forms of Seventeenth and Eighteenth Supplemental Indentures (Exhibits 4.2. and 4.3 to Form 8-K filed February 11, 2003, File No. 1-8489, incorporated by reference); Forms of Twentieth and Twenty-first Supplemental Indentures (Exhibits 4.2 and 4.3 to Form 8-K filed March 4, 2003, File No. 1-8489, incorporated by reference); Form of Twenty-second Supplemental Indenture (Exhibit 4.2 to Form 8-K filed July 22, 2003, File No. 1-8489 incorporated by reference).

 

10.1

$1,250,000,000 364-Day Credit Agreement among Dominion Resources, Inc., Virginia Electric and Power Company, Consolidated Natural Gas Company and JPMorgan Chase Bank, as Administrative Agent for the Lenders, dated as of May 29, 2003 (filed herewith).

 

10.2

Dominion Resources, Inc. Retirement Benefit Restoration Plan as adopted effective January 1, 1991 as amended and restated October 17, 2003 (filed herewith).

 

10.3

Dominion Resources, Inc. Executive Supplemental Retirement Plan, effective January 1, 1981 as amended and restated October 17, 2003 (filed herewith).

 

12

Ratio of earnings to fixed charges (filed herewith)

 

31.1

Certification by Registrant's Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).

 

31.2

Certification by Registrant's Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).

 

32

Certification to the Securities and Exchange Commission by Registrant's Chief Executive Officer and Chief Financial Officer, as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).

 

99

Condensed consolidated earnings statements (unaudited) (filed herewith).

 

 

PAGE 47

DOMINION RESOURCES, INC.
PART II. - OTHER INFORMATION


ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

(b) Reports on Form 8-K:

 

 

 

 

The following Current Reports on Form 8-K were filed with the SEC:

 

1.

Dominion filed a report on Form 8-K on July 17, 2003 relating to Dominion's press release announcing second quarter earnings.

 

2.

Dominion filed a report on Form 8-K on July 22, 2003, relating to the sale of $510,000,000 aggregate principal amount of Dominion's 2003 Series F 5.25% Senior Notes Due 2033.

 

3.

Dominion filed a report on Form 8-K on August 20, 2003 relating to the establishment of a program under which up to $2,490,000,000 aggregate principal amount of Dominion's Medium-Term Notes, Series B would be issued.

 

4.

Dominion filed a report on Form 8-K on September 22, 2003 relating to Dominion's press release regarding its telecommunications operations.

 

The Current Reports of Form 8-K listed below were furnished to the SEC during the period covered by this report and shall not be deemed "filed" for purposes of the Securities Exchange Act of 1934, as amended, or incorporated by reference into any document filed under the Securities Act of 1933, as amended, except as expressly set forth by specific reference in such filing.

 

5.

Dominion furnished a report on Form 8-K on October 14, 2003 relating to Dominion's press release regarding the costs associated with the company's storm restoration efforts following Hurricane Isabel.

 

6.

Dominion furnished a report on Form 8-K on October 21, 2003 relating to Dominion's press release announcing third quarter earnings.

 

 

SIGNATURE

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.

 

DOMINION RESOURCES, INC.
Registrant

November 7, 2003

                  /s/ Steven A. Rogers                       

 

Steven A. Rogers
Vice President and Controller
(Principal Accounting Officer)