10-Q

UNITED STATES

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, 2010

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	Exact name of registrants as specified in their charters, address of principal executive offices and registrants’ telephone number	I.R.S. Employer Identification Number
001-08489	DOMINION RESOURCES, INC.	54-1229715
001-02255	VIRGINIA ELECTRIC AND POWER COMPANY	54-0418825
	120 Tredegar Street Richmond, Virginia 23219 (804) 819-2000

State or other jurisdiction of incorporation or organization of the registrants: Virginia

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.

Dominion Resources, Inc.    Yes  x    No  ¨             Virginia Electric and Power Company    Yes  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Dominion Resources, Inc.    Yes  x    No  ¨             Virginia Electric and Power Company    Yes  ¨    No  ¨

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

Dominion Resources, Inc.

Large accelerated filer	x	Accelerated filer	¨
Non-accelerated filer	¨  (Do not check if a smaller reporting company)	Smaller reporting company	¨

Virginia Electric and Power Company

Large accelerated filer	¨	Accelerated filer	¨
Non-accelerated filer	x  (Do not check if a smaller reporting company)	Smaller reporting company	¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Dominion Resources, Inc.    Yes  ¨    No  x             Virginia Electric and Power Company    Yes  ¨    No  x

At September 30, 2010, the latest practicable date for determination, Dominion Resources, Inc. had 580,507,721 shares of common stock outstanding and Virginia Electric and Power Company had 263,010 shares of common stock outstanding. Dominion Resources, Inc. is the sole holder of Virginia Electric and Power Company’s common stock.

This combined Form 10-Q represents separate filings by Dominion Resources, Inc. and Virginia Electric and Power Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Virginia Electric and Power Company makes no representations as to the information relating to Dominion Resources, Inc.’s other operations.

COMBINED INDEX

		Page Number
	Glossary of Terms		3
	PART I. Financial Information
Item 1.	Financial Statements		5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		48
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		64
Item 4.	Controls and Procedures		65
	PART II. Other Information
Item 1.	Legal Proceedings		66
Item 1A.	Risk Factors		66
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		67
Item 6.	Exhibits		68

PAGE 2

GLOSSARY OF TERMS

The following abbreviations or acronyms used in this Form 10-Q are defined below:

Abbreviation or Acronym	Definition
AOCI	Accumulated other comprehensive income (loss)
AMR	Automated meter reading program deployed by East Ohio
ARO	Asset retirement obligation
ASLB	Atomic Safety and Licensing Board
bcf	Billion cubic feet
Bear Garden	A 580 MW combined cycle, natural gas-fired power station under construction in Buckingham County, Virginia
BREDL	Blue Ridge Environmental Defense League
CEO	Chief Executive Officer
CFO	Chief Financial Officer
CFTC	Commodity Futures Trading Commission
COL	Combined Construction Permit and Operating License
CONSOL	CONSOL Energy, Inc.
DEI	Dominion Energy, Inc.
Dodd-Frank Act	The Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010
DOE	Department of Energy
Dominion	The legal entity, Dominion Resources, Inc., one or more of Dominion Resources, Inc.’s consolidated subsidiaries (other than Virginia Power) or operating segments or the entirety of Dominion Resources, Inc. and its consolidated subsidiaries
Dominion Direct®	A dividend reinvestment and open enrollment direct stock purchase plan
DRS	Dominion Resources Services, Inc.
DTI	Dominion Transmission, Inc.
DVP	Dominion Virginia Power operating segment
East Ohio	The East Ohio Gas Company, doing business as Dominion East Ohio
E&P	Exploration & production
EPA	Environmental Protection Agency
EPS	Earnings per share
Fairless	Fairless power station
Fowler Ridge	A wind-turbine facility joint venture between Dominion and BP Alternative Energy, Inc. in Benton County, Indiana
FERC	Federal Energy Regulatory Commission
FTRs	Financial transmission rights
GAAP	U.S. generally accepted accounting principles
GHG	Greenhouse gas
Hope	Hope Gas, Inc., doing business as Dominion Hope
IRS	Internal Revenue Service
Kewaunee	Kewaunee power station
LNG	Liquefied natural gas
MD&A	Management’s Discussion and Analysis of Financial Condition and Results of Operations
Millstone	Millstone power station
Moody’s	Moody’s Investors Service
MW	Megawatt
MWh	Megawatt hour
NAAQS	National Ambient Air Quality Standard
NCEMC	North Carolina Electric Membership Corporation
NedPower	A wind-turbine facility joint venture between Dominion and Shell WindEnergy Inc. in Grant County, West Virginia
NERC	The North American Electric Reliability Corporation
NGLs	Natural gas liquids
North Anna	North Anna power station
North Carolina Commission	North Carolina Utilities Commission

PAGE 3

Abbreviation or Acronym	Definition
NOX	Nitrogen oxide
NO2	Nitrogen dioxide
NRC	Nuclear Regulatory Commission
ODEC	Old Dominion Electric Cooperative
Ohio Commission	Public Utilities Commission of Ohio
Peoples	The Peoples Natural Gas Company
PIR	Pipeline infrastructure replacement program deployed by East Ohio
PJM	PJM Interconnection, LLC
PNG Companies LLC	An indirect subsidiary of SteelRiver Infrastructure Fund North America
Riders C1 and C2	Rate adjustment clauses associated with the recovery of costs related to certain demand-side management programs
Rider R	A rate adjustment clause associated with the recovery of costs related to Bear Garden
Rider S	A rate adjustment clause associated with the recovery of costs related to the Virginia City Hybrid Energy Center
Rider T	A rate adjustment clause associated with the recovery of certain electric transmission-related expenditures
ROE	Return on equity
RTO	Regional transmission organization
SEC	Securities and Exchange Commission
SO2	Sulfur dioxide
Standard & Poor’s	Standard & Poor’s Ratings Services, a division of the McGraw-Hill Companies, Inc.
State Line	State Line power station
Surry	Surry power station
TGP	Tennessee Gas Pipeline Company
the Companies	Dominion and Virginia Power, collectively
U.S.	United States of America
US-APWR	Mitsubishi Heavy Industry’s Advanced Pressurized Water Reactor
VIE	Variable interest entity
Virginia Commission	Virginia State Corporation Commission
Virginia City Hybrid Energy Center	A 585 MW (nominal) carbon-capture compatible, clean coal powered electric generation facility under construction in Wise County, Virginia
Virginia Power	The legal entity, Virginia Electric and Power Company, one or more of its consolidated subsidiaries or operating segments or the entirety of Virginia Power and its consolidated subsidiaries
VPDES	Virginia Pollutant Discharge Elimination System
VPP	Volumetric production payment
VSWCB	Virginia State Water Control Board

PAGE 4

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended September 30,					Nine Months Ended September 30,
	2010		2009(1)			2010			2009(1)
(millions, except per share amounts)
Operating Revenue	$	3,950	$	3,630		$	11,451		$	11,622
Operating Expenses
Electric fuel and other energy-related purchases		1,180		1,072			3,164			3,211
Purchased electric capacity		116		96			333			309
Purchased gas		367		281			1,550			1,639
Other operations and maintenance		788		713			2,709			2,632
Depreciation, depletion and amortization		263		274			794			824
Other taxes		117		106			405			366
Total operating expenses		2,831		2,542			8,955			8,981
Gain on sale of Appalachian E&P operations		—		—			2,467			—
Income from operations		1,119		1,088			4,963			2,641
Other income		63		128			109			136
Interest and related charges		229		217			600			656
Income from continuing operations including noncontrolling interests before income tax expense		953		999			4,472			2,121
Income tax expense		374		360			1,803			766
Income from continuing operations including noncontrolling interests		579		639			2,669			1,355
Loss from discontinued operations(2)		—		(41	)		(147	)		(47	)
Net Income Including Noncontrolling Interests		579		598			2,522			1,308
Noncontrolling Interests		4		4			12			12
Net Income Attributable to Dominion	$	575	$	594		$	2,510		$	1,296
Amounts Attributable to Dominion:
Income from continuing operations, net of tax	$	575	$	635		$	2,657		$	1,343
Loss from discontinued operations, net of tax		—		(41	)		(147	)		(47	)
Net income attributable to Dominion	$	575	$	594		$	2,510		$	1,296
Earnings Per Common Share – Basic
Income from continuing operations	$	0.98	$	1.07		$	4.49		$	2.27
Loss from discontinued operations		—		(0.07	)		(0.25	)		(0.08	)
Net income attributable to Dominion	$	0.98	$	1.00		$	4.24		$	2.19
Earnings Per Common Share – Diluted
Income from continuing operations	$	0.98	$	1.07		$	4.48		$	2.27
Loss from discontinued operations		—		(0.07	)		(0.25	)		(0.08	)
Net income attributable to Dominion	$	0.98	$	1.00		$	4.23		$	2.19
Dividends paid per common share	$	0.4575	$	0.4375		$	1.3725		$	1.3125

(1) Dominion’s Consolidated Statements of Income for the three and nine months ended September 30, 2009 have been recast to reflect Peoples as discontinued operations, as discussed in Note 3.

(2) Includes income tax expense of $20 million for the three months ended September 30, 2009 and $13 million and $74 million for the nine months ended September 30, 2010 and 2009, respectively.

The accompanying notes are an integral part of Dominion’s Consolidated Financial Statements.

PAGE 5

DOMINION RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2010			December 31, 2009(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	446		$	48
Customer receivables (less allowance for doubtful accounts of $29 and $31)		1,728			2,050
Other receivables (less allowance for doubtful accounts of $9 and $14)		97			130
Inventories		1,222			1,185
Derivative assets		1,057			1,128
Assets held for sale		—			1,018
Regulatory assets		459			170
Prepayments		132			405
Other		854			683
Total current assets		5,995			6,817
Investments
Nuclear decommissioning trust funds		2,745			2,625
Investment in equity method affiliates		591			595
Other		275			272
Total investments		3,611			3,492
Property, Plant and Equipment
Property, plant and equipment		39,112			39,036
Accumulated depreciation, depletion and amortization		(13,056	)		(13,444	)
Total property, plant and equipment, net		26,056			25,592
Deferred Charges and Other Assets
Goodwill		3,141			3,354
Regulatory assets		1,321			1,390
Other		2,105			1,909
Total deferred charges and other assets		6,567			6,653
Total assets	$	42,229		$	42,554

(1) Dominion’s Consolidated Balance Sheet at December 31, 2009 has been derived from the audited Consolidated Financial Statements at that date.

The accompanying notes are an integral part of Dominion’s Consolidated Financial Statements.

PAGE 6

DOMINION RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	September 30, 2010			December 31, 2009(1)
(millions)
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities
Securities due within one year	$	776		$	1,137
Short-term debt		100			1,295
Accounts payable		1,342			1,401
Accrued interest, payroll and taxes		953			676
Derivative liabilities		754			679
Liabilities held for sale		—			428
Regulatory liabilities		180			536
Other		822			681
Total current liabilities		4,927			6,833
Long-Term Debt
Long-term debt		14,288			13,730
Junior subordinated notes payable to affiliates		268			268
Enhanced junior subordinated notes		1,467			1,483
Total long-term debt		16,023			15,481
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		4,366			4,244
Asset retirement obligations		1,559			1,605
Pension and other postretirement benefit liabilities		1,159			1,260
Regulatory liabilities		1,366			1,215
Other		477			474
Total deferred credits and other liabilities		8,927			8,798
Total liabilities		29,877			31,112
Commitments and Contingencies (see Note 15)
Subsidiary Preferred Stock Not Subject to Mandatory Redemption		257			257
Common Shareholders’ Equity
Common stock – no par(2)		5,702			6,525
Other paid-in capital		193			185
Retained earnings		6,386			4,686
Accumulated other comprehensive loss		(186	)		(211	)
Total common shareholders’ equity		12,095			11,185
Total liabilities and shareholders’ equity	$	42,229		$	42,554

(1) Dominion’s Consolidated Balance Sheet at December 31, 2009 has been derived from the audited Consolidated Financial Statements at that date.

(2) 1 billion shares authorized; 581 million and 599 million shares outstanding at September 30, 2010 and December 31, 2009, respectively.

The accompanying notes are an integral part of Dominion’s Consolidated Financial Statements.

PAGE 7

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

Nine Months Ended September 30,	2010			2009
(millions)
Operating Activities
Net income including noncontrolling interests	$	2,522		$	1,308
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Gain from sale of Appalachian E&P operations		(2,467	)		—
Loss from sale of Peoples		113			—
Accrued charges related to workforce reduction program		261			—
Impairment of merchant generation facility		163			—
Impairment of gas and oil properties		21			455
Depreciation, depletion and amortization (including nuclear fuel)		946			960
Deferred income taxes and investment tax credits		310			(342	)
Contribution to employee pension plans		(250	)		—
Rate settlement		(413	)		—
Other adjustments		7			(95	)
Changes in:
Accounts receivable		360			804
Inventories		(23	)		(41	)
Deferred fuel and purchased gas costs		(147	)		678
Prepayments		274			(67	)
Accounts payable		(51	)		(475	)
Accrued interest, payroll and taxes		270			(4	)
Margin deposit assets and liabilities		(23	)		(194	)
Other operating assets and liabilities		11			(5	)
Net cash provided by operating activities		1,884			2,982
Investing Activities
Plant construction and other property additions		(2,509	)		(2,884	)
Proceeds from the sale of Appalachian E&P operations		3,450			—
Proceeds from the sale of Peoples		741			—
Proceeds from sale of securities		1,938			1,258
Purchases of securities		(2,470	)		(1,294	)
Other		75			176
Net cash provided by (used in) investing activities		1,225			(2,744	)
Financing Activities
Repayment of short-term debt, net		(1,195	)		(1,381	)
Issuance of long-term debt		550			1,695
Repayment of long-term debt		(414	)		(134	)
Issuance of common stock		66			381
Repurchase of common stock		(900	)		—
Common dividend payments		(810	)		(777	)
Subsidiary preferred dividend payments		(12	)		(12	)
Other		2			(28	)
Net cash used in financing activities		(2,713	)		(256	)
Increase (decrease) in cash and cash equivalents		396			(18	)
Cash and cash equivalents at beginning of period(1)		50			71
Cash and cash equivalents at end of period(2)	$	446		$	53
Supplemental Cash Flow Information:
Significant noncash investing and financing activities
Accrued capital expenditures	$	192		$	184
Debt for equity exchange		—			56

(1) 2010 and 2009 amounts include $2 million and $5 million, respectively, of cash classified as held for sale in Dominion’s Consolidated Balance Sheets.

(2) 2009 amount includes $3 million of cash classified as held for sale in Dominion’s Consolidated Balance Sheet.

The accompanying notes are an integral part of Dominion’s Consolidated Financial Statements.

PAGE 8

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months  Ended September 30,				Nine Months  Ended September 30,
	2010		2009		2010		2009
(millions)
Operating Revenue	$	2,111	$	1,938	$	5,561	$	5,472
Operating Expenses
Electric fuel and other energy-related purchases		694		740		1,915		2,219
Purchased electric capacity		116		95		331		307
Other operations and maintenance:
Affiliated suppliers		85		109		293		310
Other		319		230		947		757
Depreciation and amortization		171		162		499		479
Other taxes		53		48		170		145
Total operating expenses		1,438		1,384		4,155		4,217
Income from operations		673		554		1,406		1,255
Other income		25		33		67		65
Interest and related charges		88		89		259		263
Income before income tax expense		610		498		1,214		1,057
Income tax expense		230		183		472		389
Net Income		380		315		742		668
Preferred dividends		4		4		12		12
Balance available for common stock	$	376	$	311	$	730	$	656

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

PAGE 9

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2010			December 31, 2009(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	22		$	19
Customer accounts receivable (less allowance for doubtful accounts of $10 and $12)		937			880
Other receivables (less allowance for doubtful accounts of $6 at both dates)		52			72
Inventories (average cost method)		603			614
Regulatory assets		278			116
Prepayments		114			52
Other		42			343
Total current assets		2,048			2,096
Investments
Nuclear decommissioning trust funds		1,257			1,204
Other		3			4
Total investments		1,260			1,208
Property, Plant and Equipment
Property, plant and equipment		27,163			25,643
Accumulated depreciation and amortization		(9,683	)		(9,314	)
Total property, plant and equipment, net		17,480			16,329
Deferred Charges and Other Assets
Intangible assets		209			217
Regulatory assets		292			200
Other		240			68
Total deferred charges and other assets		741			485
Total assets	$	21,529		$	20,118

(1) Virginia Power’s Consolidated Balance Sheet at December 31, 2009 has been derived from the audited Consolidated Financial Statements at that date.

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

PAGE 10

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	September 30, 2010		December 31, 2009(1)
(millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Securities due within one year	$	245	$	245
Short-term debt		100		442
Accounts payable		451		390
Payables to affiliates		66		67
Affiliated current borrowings		264		2
Accrued interest, payroll and taxes		279		213
Regulatory liabilities		152		491
Other		416		358
Total current liabilities		1,973		2,208
Long-Term Debt		6,502		6,213
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,514		2,359
Asset retirement obligations		660		636
Regulatory liabilities		1,144		995
Other		307		277
Total deferred credits and other liabilities		4,625		4,267
Total liabilities		13,100		12,688
Commitments and Contingencies (see Note 15)
Preferred Stock Not Subject to Mandatory Redemption		257		257
Common Shareholder’s Equity
Common stock – no par(2)		5,373		4,738
Other paid-in capital		1,111		1,110
Retained earnings		1,669		1,299
Accumulated other comprehensive income		19		26
Total common shareholder’s equity		8,172		7,173
Total liabilities and shareholder’s equity	$	21,529	$	20,118

(1) Virginia Power’s Consolidated Balance Sheet at December 31, 2009 has been derived from the audited Consolidated Financial Statements at that date.

(2) 300,000 shares authorized; 263,010 and 241,710 shares outstanding at September 30, 2010 and December 31, 2009, respectively.

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

PAGE 11

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Nine Months Ended September 30,	2010			2009
(millions)
Operating Activities
Net income	$	742		$	668
Adjustments to reconcile net income to net cash provided by operating activities:
Accrued charges related to workforce reduction program		98			—
Depreciation and amortization (including nuclear fuel)		584			556
Deferred income taxes and investment tax credits		399			(103	)
Rate settlement		(413	)		—
Contribution to employee pension plans		(119	)		—
Other adjustments		21			(44	)
Changes in:
Accounts receivable		(38	)		24
Affiliated accounts receivable and payable		1			(15	)
Inventories		10			(55	)
Deferred fuel expenses		(126	)		514
Accounts payable		80			(49	)
Accrued interest, payroll and taxes		66			47
Prepayments		(62	)		(40	)
Other operating assets and liabilities		(5	)		83
Net cash provided by operating activities		1,238			1,586
Investing Activities
Plant construction and other property additions		(1,579	)		(1,745	)
Purchases of nuclear fuel		(114	)		(90	)
Purchases of securities		(976	)		(624	)
Proceeds from sales of securities		959			607
Other		2			(53	)
Net cash used in investing activities		(1,708	)		(1,905	)
Financing Activities
Repayment of short-term debt, net		(342	)		(297	)
Issuance of affiliated current borrowings, net		897			646
Issuance of long-term debt		300			460
Repayment of long-term debt		(11	)		(120	)
Common dividend payments		(360	)		(366	)
Preferred dividend payments		(12	)		(12	)
Other		1			4
Net cash provided by financing activities		473			315
Increase (decrease) in cash and cash equivalents		3			(4	)
Cash and cash equivalents at beginning of period		19			27
Cash and cash equivalents at end of period	$	22		$	23
Supplemental Cash Flow Information
Significant noncash investing and financing activities:
Accrued capital expenditures	$	114		$	78
Conversion of short-term borrowings payable to Dominion to equity		636			—

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

PAGE 12

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1. Nature of Operations

Dominion, headquartered in Richmond, Virginia, is one of the nation’s largest producers and transporters of energy. Dominion’s operations are conducted through various subsidiaries, including Virginia Power, a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and northeastern North Carolina.

As discussed in Note 3, Dominion completed the sales of its Pennsylvania gas distribution operations and substantially all of its Appalachian E&P operations in February and April 2010, respectively.

Note 2. Significant Accounting Policies

As permitted by the rules and regulations of the SEC, Dominion’s and Virginia Power’s 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 GAAP. These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009 and their Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010. Due to the sale of substantially all of Dominion’s Appalachian E&P operations during the second quarter of 2010, accounting for gas and oil operations is no longer considered a significant accounting policy. There have been no other material changes with regard to the significant accounting policies previously disclosed in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009.

In Dominion’s and Virginia Power’s opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position as of September 30, 2010, their results of operations for the three and nine months ended September 30, 2010 and 2009 and their cash flows for the nine months ended September 30, 2010 and 2009. Such adjustments are normal and recurring in nature unless otherwise noted.

The Companies make certain estimates and assumptions in preparing their Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses for the periods presented. Actual results may differ from those estimates.

Dominion’s and Virginia Power’s accompanying unaudited Consolidated Financial Statements include, after eliminating intercompany transactions and balances, their accounts and those of their respective majority-owned subsidiaries.

The results of operations for 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, electric fuel and other energy-related purchases, purchased gas expenses and other factors.

Certain amounts in Dominion’s and Virginia Power’s 2009 Consolidated Financial Statements and Notes have been recast to conform to the 2010 presentation.

Amounts disclosed for Dominion are inclusive of Virginia Power, where applicable.

Note 3. Dispositions

Sale of Appalachian E&P Operations

In April 2010, Dominion completed the sale of substantially all of its Appalachian E&P operations to a newly-formed subsidiary of CONSOL for approximately $3.5 billion. The transaction includes the mineral rights to approximately 491,000 acres in the Marcellus Shale formation. Dominion retained certain oil and natural gas wells located on or near its natural gas storage fields. The transaction generated after-tax proceeds of approximately $2.2 billion and resulted in an after-tax gain of approximately $1.4 billion, which includes a $134 million write-off of goodwill. Proceeds from the sale have been or will be used to pay taxes on the gain, offset all of Dominion’s equity needs for 2010 and its market equity issuances for 2011, repurchase common stock, fund contributions to Dominion’s pension plans and the Dominion Foundation, reduce debt and offset the majority of the impact of Virginia Power’s rate case settlement.

PAGE 13

The results of operations for Dominion’s Appalachian E&P business are not reported as discontinued operations in the Consolidated Statements of Income since Dominion did not sell its entire U.S. cost pool.

Due to the sale, hedge accounting was discontinued for certain cash flow hedges since it became probable that the forecasted sales of gas would not occur. In connection with the discontinuance of hedge accounting for these contracts, Dominion recognized a $42 million ($25 million after-tax) benefit, recorded in operating revenue in its Consolidated Statement of Income, reflecting the reclassification of gains from AOCI to earnings for these contracts in March 2010.

Sale of Peoples

In February 2010, Dominion completed the sale of Peoples to PNG Companies LLC and netted after-tax proceeds of approximately $542 million. The sale resulted in an after-tax loss of approximately $132 million, which included a $79 million write-off of goodwill as well as post-closing adjustments. The sale also resulted in after-tax expenses of approximately $27 million, including transaction and benefit-related costs. In addition, Peoples had income from operations of $12 million after-tax during 2010.

Prior to March 31, 2010, Dominion did not report Peoples as discontinued operations since it expected to have significant continuing cash flows related primarily to the sale of natural gas production from its Appalachian E&P business to Peoples. Due to the sale of its Appalachian E&P business, Dominion will not have significant continuing cash flows with Peoples; therefore, the results of Peoples were reclassified to discontinued operations in the Consolidated Statements of Income for all periods presented.

The carrying amounts of the major classes of assets and liabilities classified as held for sale in Dominion’s Consolidated Balance Sheet were as follows:

	December 31, 2009
(millions)
ASSETS
Current Assets
Customer receivables	$	87
Other		56
Total current assets		143
Property, Plant and Equipment
Property, plant and equipment		985
Accumulated depreciation, depletion and amortization		(284	)
Total property, plant and equipment, net		701
Deferred Charges and Other Assets
Regulatory assets		125
Other		49
Total deferred charges and other assets		174
Assets held for sale	$	1,018
LIABILITIES
Current Liabilities	$	133
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		238
Other		57
Total deferred credits and other liabilities		295
Liabilities held for sale	$	428

PAGE 14

The following table presents selected information regarding the results of operations of Peoples, which are reported as discontinued operations in the Consolidated Statements of Income:

	Three Months  Ended September 30,					Nine Months  Ended September 30,
	2010		2009			2010			2009
(millions)
Operating revenue	$	—	$	38		$	67		$	328
Income (loss) before income taxes		—		(21	)		(134	)		27

Note 4. Ceiling Test

Dominion follows the full cost method of accounting for its gas and oil E&P activities, which subjects capitalized costs to a quarterly ceiling test using hedge-adjusted prices. Due to the April 2010 sale of substantially all of its Appalachian E&P operations, as of September 30, 2010 Dominion no longer has any significant gas and oil properties subject to the ceiling test calculation.

At March 31, 2010, Dominion recorded a ceiling test impairment charge of $21 million ($13 million after-tax) in other operations and maintenance expense in its Consolidated Statement of Income primarily due to a decline in hedge-adjusted prices reflecting the discontinuance of hedge accounting for certain cash flow hedges, as discussed in Note 3.

During the nine months ended September 30, 2009, Dominion recorded a ceiling test impairment charge of $455 million ($281 million after-tax) in other operations and maintenance expense in its Consolidated Statement of Income. Excluding the effects of hedge-adjusted prices in calculating the ceiling limitation, the impairment charge would have been $631 million ($378 million after-tax).

Note 5. Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2010		2009		2010		2009
(millions)
Dominion
Electric sales:
Regulated	$	2,083	$	1,905	$	5,488	$	5,377
Nonregulated		1,072		999		2,857		2,917
Gas sales:
Regulated		25		26		209		403
Nonregulated		375		351		1,502		1,671
Gas transportation and storage		289		242		1,070		924
Other		106		107		325		330
Total operating revenue	$	3,950	$	3,630	$	11,451	$	11,622
Virginia Power
Regulated electric sales	$	2,083	$	1,905	$	5,488	$	5,377
Other		28		33		73		95
Total operating revenue	$	2,111	$	1,938	$	5,561	$	5,472

PAGE 15

Note 6. Income Taxes

Continuing Operations

For continuing operations, including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to Dominion’s and Virginia Power’s effective income tax rate as follows:

	Dominion						Virginia Power
Nine Months Ended September 30,	2010			2009			2010			2009
U.S. statutory rate		35.0	%		35.0	%		35.0	%		35.0	%
Increases (reductions) resulting from:
Legislative changes		1.2			0.4			1.3			—
State taxes, net of federal benefit		4.5			3.5			3.9			3.7
Domestic production activities deduction		(0.4	)		(0.7	)		(0.9	)		(0.6	)
Non-deductible goodwill		0.9			—			—			—
Other, net		(0.9	)		(2.1	)		(0.4	)		(1.3	)
Effective tax rate		40.3	%		36.1	%		38.9	%		36.8	%

Dominion’s and Virginia Power’s effective tax rates in 2010 reflect a reduction of deferred tax assets resulting from the enactment of the Patient Protection and Affordable Care Act and the Health Care and Education Affordability Reconciliation Act of 2010, which eliminated the employer’s deduction, beginning in 2013, for that portion of its retiree prescription drug coverage cost that is being reimbursed by the Medicare Part D subsidy. In addition, Dominion’s effective tax rate in 2010 includes the impact of goodwill written off with the sale of the Appalachian E&P operations that is not deductible for tax purposes.

During the nine months ended September 30, 2010, Dominion’s and Virginia Power’s unrecognized tax benefits changed as follows:

	Dominion			Virginia Power
(millions)
Beginning balance	$	291		$	121
Increases – prior period positions		15			4
Decreases – prior period positions		(60	)		(26	)
Current period positions		27			16
Other		(3	)		—
Ending balance	$	270		$	115

In 2010, the IRS began its examination of Dominion’s consolidated tax returns for tax years 2006 and 2007, and Dominion began settlement negotiations with the Appellate Division of the IRS regarding adjustments proposed in the examination of its consolidated tax returns for 2004 and 2005.

In September 2010, the Appellate Division of the IRS informed Dominion that the U.S. Congressional Joint Committee on Taxation had approved the settlement of tax years 2002 and 2003 for Dominion and its consolidated subsidiaries. The settlement excludes two issues, for which Dominion has reserved the right to litigate and pursue claims for refunds.

With Dominion’s appeals of assessments received from tax authorities, including settlement negotiations with the Appellate Division of the IRS regarding tax years 2004 and 2005 and the ongoing IRS examination of tax years 2006 and 2007, it is reasonably possible that certain unrecognized tax benefits could decrease during the next 12 months by up to $25 million for Dominion and up to $20 million for Virginia Power. Dominion’s unrecognized tax benefits could also be reduced over the next 12 months by $13 million, including $3 million for Virginia Power, to recognize prior period amounts becoming otherwise deductible in the current period. In addition, unrecognized tax benefits may increase for Dominion and Virginia Power by $20 million during the next 12 months for current period amounts related to certain tax positions initially taken in prior year returns for recurring business activities. Since the uncertainty for the majority of these unrecognized tax benefits involves only the timing of the deductions, no material impact on earnings is expected.

Discontinued Operations

Income tax expense in 2010 for Dominion’s discontinued operations primarily reflects the impact of goodwill written off in the sale of Peoples that is not deductible for tax purposes and the reversal of deferred taxes for which the benefit was offset by the reversal of income tax-related regulatory assets.

PAGE 16

Income tax expense in 2009 for Dominion’s discontinued operations also reflects the impact of these items. Since the sale of Peoples was originally expected to occur in 2009, the tax effects related to the sale were included in the determination of Dominion’s estimated annual effective tax rate in 2009.

2010 Legislation

In September 2010, the President of the U.S. signed the Small Business Jobs Act of 2010 which provides a one-year extension for the fifty percent bonus depreciation allowance for qualifying expenditures. Dominion and Virginia Power expect to claim bonus depreciation, which will result in reduced income taxes payable and increased deferred tax liabilities.

Note 7. Earnings Per Share

The following table presents the calculation of Dominion’s basic and diluted EPS:

	Three Months  Ended September 30,				Nine Months Ended September 30,
	2010		2009		2010		2009
(millions, except EPS)
Net income attributable to Dominion	$	575	$	594	$	2,510	$	1,296
Average shares of common stock outstanding – Basic		585.0		595.9		591.7		591.7
Net effect of potentially dilutive securities(1)		1.4		0.4		1.1		0.3
Average shares of common stock outstanding – Diluted		586.4		596.3		592.8		592.0
Earnings Per Common Share – Basic	$	0.98	$	1.00	$	4.24	$	2.19
Earnings Per Common Share – Diluted	$	0.98	$	1.00	$	4.23	$	2.19

(1) Potentially dilutive securities consist of options, goal-based stock and contingently convertible senior notes.

Potentially dilutive securities with the right to acquire approximately 0.5 million and 1.6 million common shares for the three and nine months ended September 30, 2009, respectively, were not included in the period’s calculation of diluted EPS because the exercise or purchase prices of those instruments were greater than the average market price of Dominion’s common shares. There were no potentially dilutive securities excluded from the calculation of diluted EPS for the three and nine months ended September 30, 2010.

Note 8. Comprehensive Income

The following table presents Dominion’s total comprehensive income:

	Three Months  Ended September 30,						Nine Months  Ended September 30,
	2010			2009			2010			2009
(millions)
Net income including noncontrolling interests	$	579		$	598		$	2,522		$	1,308
Other comprehensive income (loss):
Net other comprehensive loss associated with effective portion of changes in fair value of derivatives designated as cash flow hedges, net of taxes and amounts reclassified to earnings		(56	)		(156	)		(61	)		(117	)
Other, net of tax(1)		70			67			86			144
Other comprehensive income (loss)		14			(89	)		25			27
Comprehensive income including noncontrolling interests		593			509			2,547			1,335
Noncontrolling interests		4			4			12			12
Total comprehensive income attributable to Dominion	$	589		$	505		$	2,535		$	1,323

(1) Primarily represents a net increase in unrealized gains on investments held in nuclear decommissioning trusts.

PAGE 17

The following table presents Virginia Power’s total comprehensive income:

	Three Months  Ended September 30,						Nine Months  Ended September 30,
	2010			2009			2010			2009
(millions)
Net income	$	380		$	315		$	742		$	668
Other comprehensive income (loss):
Net other comprehensive income (loss) associated with effective portion of changes in fair value of derivatives designated as cash flow hedges, net of taxes and amounts reclassified to earnings		(1	)		(2	)		(9	)		6
Other, net of tax		6			5			2			12
Other comprehensive income (loss)		5			3			(7	)		18
Total comprehensive income	$	385		$	318		$	735		$	686

PAGE 18

Note 9. Fair Value Measurements

Dominion’s and Virginia Power’s fair value measurements are made in accordance with the policies discussed in Note 7 to the Consolidated Financial Statements in their Annual Report on Form 10-K for the year ended December 31, 2009. See Note 10 in this report for further information about their derivatives and hedge accounting activities.

Fair values are based on inputs and assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. The inputs and assumptions include the following:

For commodity and foreign currency derivative contracts:

• Forward commodity prices

• Forward foreign currency prices

• Price volatility

• Volumes

• Commodity location

• Interest rates

• Credit quality of counterparties and Dominion and Virginia Power

• Credit enhancements

• Time value

For interest rate derivative contracts:

• Interest rate curves

• Credit quality of counterparties and Dominion and Virginia Power

• Credit enhancements

• Time value

For investments:

• Quoted securities prices

• Securities trading information including volume and restrictions

• Maturity

• Interest rates

• Credit quality

• Net asset value (only for investments in partnerships)

Dominion and Virginia Power regularly evaluate and validate the inputs used to estimate fair value by a number of methods, including review and verification of models, as well as various market price verification procedures such as the use of pricing services and multiple broker quotes to support the market price of the various commodities in which the Companies transact.

For derivative contracts, Dominion and Virginia Power recognize transfers among Level 1, Level 2 and Level 3 based on fair values as of the first day of the month in which the transfer occurs. Transfers out of Level 3 represent assets and liabilities that were previously classified as Level 3 for which the inputs became observable based on the criteria discussed in Note 7 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009 for classification in either Level 1 or Level 2. Because the activity and liquidity of commodity markets vary substantially between regions and time periods, the availability of observable inputs for substantially the full term and value of the Companies’ over-the-counter derivative contracts is subject to change.

PAGE 19

At September 30, 2010, Dominion’s and Virginia Power’s net balance of commodity derivatives categorized as Level 3 fair value measurements was a net liability of $17 million and $8 million, respectively. A hypothetical 10% increase in commodity prices would increase Dominion’s and Virginia Power’s Level 3 net liability by $64 million and $3 million, respectively, while a hypothetical 10% decrease in commodity prices would decrease Dominion’s and Virginia Power’s Level 3 net liability by $65 million and $3 million, respectively.

Non-recurring Fair Value Measurements

Dominion

In June 2010, Dominion evaluated State Line, a coal-fired merchant power station with minimal environmental controls, for impairment due to the station’s relatively low level of profitability combined with the EPA’s issuance in June 2010 of a new stringent 1-hour primary NAAQS for SO₂ that will likely require significant environmental capital expenditures in the future. As a result of this evaluation, Dominion recorded an impairment charge of $163 million ($95 million after-tax) in other operations and maintenance expense in its Consolidated Statement of Income, to write down State Line’s long-lived assets to their estimated fair value of $59 million. As management was not aware of any recent market transactions for comparable assets with sufficient transparency to develop a market approach to fair value, Dominion relied on the income approach (discounted cash flows) to estimate the fair value of State Line’s long-lived assets. This was considered a Level 3 fair value measurement due to the use of significant unobservable inputs including estimates of future power and other commodity prices.

During the first quarter of 2009, Dominion evaluated an equity method investment for impairment and recorded a $23 million impairment in other income (loss) in its Consolidated Statement of Income. The resulting fair value of $10 million was estimated using an expected present value cash flow model and was considered a Level 3 fair value measurement due to the use of significant unobservable inputs related to the timing and amount of future equity distributions based on the investee’s future financing structure, contractual and market based revenues and operating costs.

Virginia Power

In September 2010, Virginia Power evaluated its SO₂ emissions allowances not expected to be consumed by its generating units for potential impairment due to the significant decline in market prices since the July 2010 release of the EPA’s proposed Transport Rule, as discussed in Note 15. As a result of this evaluation, Virginia Power recorded an impairment charge of $13 million ($8 million after-tax) in other operations and maintenance expense in its Consolidated Statement of Income, to write down its SO₂ emission allowances not expected to be consumed to their estimated fair value of less than $1 million. Due to the absence of market activity for future SO₂ vintage year allowances, Virginia Power could not develop a market approach to fair value and therefore relied on the income approach to estimate the fair value of these SO₂ emission allowances, which was considered a Level 3 fair value measurement given the use of significant unobservable inputs including estimates of future SO₂ emissions allowance prices.

PAGE 20

Recurring Fair Value Measurements

Dominion

The following table presents Dominion’s assets and liabilities that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions:

	Level 1		Level 2		Level 3		Total
(millions)
As of September 30, 2010
Assets
Derivatives:
Commodity	$	87	$	1,086	$	59	$	1,232
Interest rate		—		63		—		63
Investments(1):
Equity securities:
U.S.:
Large cap		1,547		—		—		1,547
Other		49		—		—		49
Non-U.S.:
Large cap		11		—		—		11
Fixed Income:
Corporate debt instruments		—		346		—		346
U.S. Treasury securities and agency debentures		274		160		—		434
State and municipal		—		265		—		265
Other		—		21		—		21
Cash equivalents and other		8		98		—		106
Total assets	$	1,976	$	2,039	$	59	$	4,074
Liabilities
Derivatives:
Commodity	$	11	$	844	$	76	$	931
Total liabilities	$	11	$	844	$	76	$	931
As of December 31, 2009
Assets
Derivatives:
Commodity	$	85	$	1,058	$	41	$	1,184
Interest rate		—		176		—		176
Foreign currency		—		2		—		2
Investments(1):
Equity securities:
U.S.:
Large cap		1,520		—		—		1,520
Other		43		1		—		44
Non-U.S.:
Large cap		12		—		—		12
Fixed Income:
Corporate debt instruments		—		253		—		253
U.S. Treasury securities and agency debentures		216		78		—		294
State and municipal		—		434		—		434
Other		—		4		—		4
Cash equivalents and other		—		54		—		54
Total assets	$	1,876	$	2,060	$	41	$	3,977
Liabilities
Derivatives:
Commodity	$	17	$	736	$	107	$	860
Interest rate		—		1		—		1
Total liabilities	$	17	$	737	$	107	$	861

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

PAGE 21

The following table presents the net change in Dominion’s assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:

	Three Months  Ended September 30,						Nine Months  Ended September 30,
	2010			2009			2010			2009
(millions)
Beginning balance	$	32		$	31		$	(66	)	$	99
Total realized and unrealized gains (losses):
Included in earnings		27			3			40			(128	)
Included in other comprehensive income (loss)		(65	)		(7	)		20			(95	)
Included in regulatory assets/liabilities		(13	)		(45	)		1			10
Purchases, issuances and settlements		(23	)		5			(41	)		118
Transfers out of Level 3		25			2			29			(15	)
Ending balance	$	(17	)	$	(11	)	$	(17	)	$	(11	)
The amount of gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date	$	4		$	7		$	(3	)	$	2

The following table presents Dominion’s gains and losses included in earnings in the Level 3 fair value category:

	Operating revenue			Electric fuel and  other energy-related purchases			Purchased gas			Total
(millions)
Three Months Ended September 30, 2010
Total gains (losses) included in earnings	$	5		$	22		$	—		$	27
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date		4			—			—			4
Three Months Ended September 30, 2009
Total gains (losses) included in earnings	$	17		$	(14	)	$	—		$	3
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date		6			—			1			7
Nine Months Ended September 30, 2010
Total gains (losses) included in earnings	$	(5	)	$	49		$	(4	)	$	40
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date		(3	)		—			—			(3	)
Nine Months Ended September 30, 2009
Total gains (losses) included in earnings	$	31		$	(152	)	$	(7	)	$	(128	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date		5			—			(3	)		2

PAGE 22

Virginia Power

The following table presents Virginia Power’s assets and liabilities that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions:

	Level 1		Level 2		Level 3		Total
(millions)
As of September 30, 2010
Assets
Derivatives:
Commodity	$	—	$	15	$	5	$	20
Interest rate		—		4		—		4
Investments(1):
Equity securities:
U.S.:
Large cap		614		—		—		614
Other		22		—		—		22
Fixed income:
Corporate debt instruments		—		234		—		234
U.S. Treasury securities and agency debentures		109		49		—		158
State and municipal		—		86		—		86
Other		—		16		—		16
Cash equivalents and other		—		53		—		53
Total assets	$	745	$	457	$	5	$	1,207
Liabilities
Derivatives:
Commodity	$	—	$	9	$	13	$	22
Total liabilities	$	—	$	9	$	13	$	22
As of December 31, 2009
Assets
Derivatives:
Commodity	$	—	$	30	$	2	$	32
Interest rate		—		86		—		86
Foreign currency		—		2		—		2
Investments(1):
Equity securities:
U.S.:
Large cap		615		—		—		615
Other		19		—		—		19
Fixed Income:
Corporate debt instruments		—		161		—		161
U.S. Treasury securities and agency debentures		90		8		—		98
State and municipal		—		189		—		189
Other		—		3		—		3
Cash equivalents and other		—		16		—		16
Total assets	$	724	$	495	$	2	$	1,221
Liabilities
Derivatives:
Commodity	$	—	$	3	$	12	$	15
Total liabilities	$	—	$	3	$	12	$	15

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

PAGE 23

The following table presents the net change in Virginia Power’s assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:

	Three Months  Ended September 30,						Nine Months  Ended September 30,
	2010			2009			2010			2009
(millions)
Beginning balance	$	5		$	(8	)	$	(10	)	$	(69	)
Total realized and unrealized gains (losses):
Included in earnings		22			(14	)		48			(152	)
Included in regulatory assets/liabilities		(13	)		(45	)		2			10
Purchases, issuances and settlements		(22	)		15			(48	)		157
Transfers out of Level 3		—			—			—			2
Ending balance	$	(8	)	$	(52	)	$	(8	)	$	(52	)

The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases expense in Virginia Power’s Consolidated Statements of Income for the three and nine months ended September 30, 2010 and 2009. There were no unrealized gains and losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the three and nine months ended September 30, 2010 and 2009.

Fair Value of Financial Instruments

Substantially all of Dominion’s and Virginia Power’s financial instruments are recorded at fair value, with the exception of the instruments described below that are reported at historical cost. Estimated fair values have been determined using available market information and valuation methodologies considered appropriate by management. The carrying amount of cash and cash equivalents, customer and other receivables, short-term debt and accounts payable are representative of fair value because of the short-term nature of these instruments. For Dominion’s and Virginia Power’s financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows:

	September 30, 2010				December 31, 2009
	Carrying Amount		Estimated Fair Value(1)		Carrying Amount		Estimated Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	15,064	$	17,352	$	14,867	$	15,970
Junior subordinated notes payable to affiliates		268		265		268		255
Enhanced junior subordinated notes		1,467		1,573		1,483		1,487
Subsidiary preferred stock(3)		257		252		257		251
Virginia Power
Long-term debt, including securities due within one year(2)	$	6,747	$	7,771	$	6,458	$	6,977
Preferred stock(3)		257		252		257		251

(1) Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. The carrying amount of debt issues with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.

(2) Includes amounts which represent the unamortized discount and premium. At September 30, 2010 and December 31, 2009, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $59 million and $23 million, respectively.

(3) Includes issuance expenses of $2 million at September 30, 2010 and December 31, 2009.

Note 10. Derivatives and Hedge Accounting Activities

Dominion’s and Virginia Power’s accounting policies and objectives and strategies for using derivative instruments are discussed in Note 2 to the Consolidated Financial Statements in their Annual Report on Form 10-K for the year ended December 31, 2009. See Note 9 in this report for further information about fair value measurements and associated valuation methods for derivatives.

PAGE 24

Dominion

The following table presents the volume of Dominion’s derivative activity as of September 30, 2010. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting deals, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price(1)		516		116
Basis(1)		1,107		522
Electricity (MWh):
Fixed price(2)		22,096,134		9,608,229
FTRs		76,735,785		2,208,448
Capacity (MW)		1,448,200		4,339,950
Liquids (gallons)(3)		149,184,000		380,772,000
Interest rate	$	75,000,000	$	750,000,000

(1) Includes options.

(2) Includes power options.

(3) Includes NGL and oil derivatives.

For the three and nine months ended September 30, 2010 and 2009, gains or losses on hedging instruments determined to be ineffective were not material. Amounts excluded from the assessment of effectiveness include gains or losses attributable to changes in the time value of options and changes in the differences between spot prices and forward prices and were not material for the three and nine months ended September 30, 2010 and 2009.

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion’s Consolidated Balance Sheet at September 30, 2010:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings during the  next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	(24	)	$	(10	)		51 months
Electricity		204			168			32 months
NGLs		(2	)		(2	)		51 months
Other		10			3			56 months
Interest rate		32			(1	)		339 months
Total	$	220		$	158

The amounts that will be reclassified from AOCI 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 and will vary from the expected amounts presented above as a result of changes in market prices, interest rates and foreign exchange rates.

The sale of the majority of Dominion’s remaining E&P operations resulted in the discontinuance of hedge accounting for certain cash flow hedges, as discussed in Note 3.

In addition, changes to Dominion’s financing needs during the first and second quarters of 2010 resulted in the discontinuance of hedge accounting for certain cash flow hedges since it was determined that the forecasted interest payments would not occur. In connection with the discontinuance of hedge accounting for these contracts, Dominion recognized a benefit recorded to interest and related charges reflecting the reclassification of gains from AOCI to earnings of $110 million ($67 million after-tax) for the nine months ended September 30, 2010. The reclassification of gains from AOCI to earnings was partially offset by subsequent changes in fair value of $37 million ($23 million after-tax) for the nine months ended September 30, 2010.

PAGE 25

Fair Value and Gains and Losses on Derivative Instruments

The following table presents the fair values of Dominion’s derivatives and where they are presented in its Consolidated Balance Sheets:

	Fair Value – Derivatives under Hedge Accounting		Fair Value – Derivatives not under Hedge Accounting		Total Fair Value
(millions)
September 30, 2010
ASSETS
Current Assets
Commodity	$	461	$	572	$	1,033
Interest rate		24		—		24
Total current derivative assets		485		572		1,057
Noncurrent Assets
Commodity		111		88		199
Interest rate		39		—		39
Total noncurrent derivative assets(1)		150		88		238
Total derivative assets	$	635	$	660	$	1,295
LIABILITIES
Current Liabilities
Commodity	$	185	$	569	$	754
Total current derivative liabilities		185		569		754
Noncurrent Liabilities
Commodity		67		110		177
Total noncurrent derivative liabilities(2)		67		110		177
Total derivative liabilities	$	252	$	679	$	931
December 31, 2009
ASSETS
Current Assets
Commodity	$	445	$	507	$	952
Interest rate		174		—		174
Foreign currency		2		—		2
Total current derivative assets		621		507		1,128
Noncurrent Assets
Commodity		132		100		232
Interest rate		2		—		2
Total noncurrent derivative assets(1)		134		100		234
Total derivative assets	$	755	$	607	$	1,362
LIABILITIES
Current Liabilities
Commodity	$	147	$	532	$	679
Total current derivative liabilities		147		532		679
Noncurrent Liabilities
Commodity		61		120		181
Interest rate		1		—		1
Total noncurrent derivative liabilities(2)		62		120		182
Total derivative liabilities	$	209	$	652	$	861

(1) Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheets.

(2) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheets.

PAGE 26

Derivatives in cash flow hedging relationships	Amount of Gain (Loss) Recognized in AOCI  on Derivatives (Effective Portion)(1)			Amount of Gain (Loss) Reclassified from AOCI to Income			Increase (Decrease) in Derivatives Subject to Regulatory Treatment(2)
(millions)
Three Months Ended September 30, 2010
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	88
Purchased gas					(6	)
Electric fuel and other energy-related purchases					4
Purchased electric capacity					1
Total commodity	$	(5	)		87		$	(6	)
Interest rate(3)		—			—			1
Foreign currency(4)		—			—			—
Total	$	(5	)	$	87		$	(5	)
Three Months Ended September 30, 2009
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	307
Purchased gas					(16	)
Electric fuel and other energy-related purchases					(2	)
Purchased electric capacity					1
Total commodity	$	50			290		$	4
Interest rate(3)		(15	)		(1	)		(18	)
Foreign currency(4)		—			1			(2	)
Total	$	35		$	290		$	(16	)
Nine Months Ended September 30, 2010
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	383
Purchased gas					(122	)
Electric fuel and other energy-related purchases					(4	)
Purchased electric capacity					3
Total commodity	$	277			260		$	(17	)
Interest rate(3)		(3	)		109			(23	)
Foreign currency(4)		—			1			(2	)
Total	$	274		$	370		$	(42	)
Nine Months Ended September 30, 2009
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	829
Purchased gas					(99	)
Electric fuel and other energy-related purchases					(9	)
Purchased electric capacity					4
Total commodity	$	424			725		$	9
Interest rate(3)		109			(3	)		57
Foreign currency(4)		1			2			(2	)
Total	$	534		$	724		$	64

(1) Amounts deferred into AOCI have no associated effect in Dominion’s Consolidated Statements of Income.

(2) Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion’s Consolidated Statements of Income.

(3) Amounts recorded in Dominion’s Consolidated Statements of Income are classified in interest and related charges.

(4) Amounts recorded in Dominion’s Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.

PAGE 27

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months  Ended September 30,						Nine Months  Ended September 30,
Derivatives not designated as hedging instruments	2010			2009			2010			2009
(millions)
Derivative Type and Location of Gains (Losses)
Commodity
Operating revenue	$	45		$	28		$	71		$	74
Purchased gas		(13	)		(15	)		(42	)		(61	)
Electric fuel and other energy-related purchases		23			(14	)		48			(151	)
Interest Rate(2)		—			—			(37	)		—
Total	$	55		$	(1	)	$	40		$	(138	)

(1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion’s Consolidated Statements of Income.

(2) Amounts are recorded in interest and related charges in Dominion’s Consolidated Statements of Income.

Virginia Power

The following table presents the volume of Virginia Power’s derivative activity as of September 30, 2010. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting deals, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price		4		—
Basis		2		—
Electricity (MWh):
Fixed price		901,600		—
FTRs		76,296,000		2,208,448
Capacity (MW)		352,600		304,500
Interest rate	$	75,000,000		—

For the three and nine months ended September 30, 2010 and 2009, gains or losses on hedging instruments determined to be ineffective were not material. Amounts excluded from the assessment of effectiveness include gains or losses attributable to changes in the time value of options and changes in the differences between spot prices and forward prices and were not material for the three and nine months ended September 30, 2010 and 2009.

The following table presents selected information related to gains on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at September 30, 2010:

	AOCI After-Tax		Amounts Expected to be Reclassified to Earnings during the  next 12 Months After-Tax		Maximum Term
(millions)
Interest rate	$	3	$	—		339 months
Other		1		1		44 months
Total	$	4	$	1

The amounts that will be reclassified from AOCI 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 and will vary from the expected amounts presented above as a result of changes in market prices, interest rates and foreign exchange rates.

PAGE 28

Fair Value and Gains and Losses on Derivative Instruments

The following table presents the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets:

	Fair Value – Derivatives under Hedge Accounting		Fair Value – Derivatives not under Hedge Accounting		Total Fair Value
(millions)
September 30, 2010
ASSETS
Current Assets
Commodity	$	15	$	5	$	20
Interest rate		4		—		4
Total current derivative assets(1)		19		5		24
Total derivative assets	$	19	$	5	$	24
LIABILITIES
Current Liabilities
Commodity	$	6	$	13	$	19
Total current derivative liabilities(3)		6		13		19
Noncurrent Liabilities
Commodity		3		—		3
Total noncurrent derivative liabilities(4)		3		—		3
Total derivative liabilities	$	9	$	13	$	22
December 31, 2009
ASSETS
Current Assets
Commodity	$	20	$	2	$	22
Interest rate		86		—		86
Foreign currency		2		—		2
Total current derivative assets(1)		108		2		110
Noncurrent Assets
Commodity		10		—		10
Total noncurrent derivative assets(2)		10		—		10
Total derivative assets	$	118	$	2	$	120
LIABILITIES
Current Liabilities
Commodity	$	1	$	12	$	13
Total current derivative liabilities(3)		1		12		13
Noncurrent Liabilities
Commodity		2		—		2
Total noncurrent derivative liabilities(4)		2		—		2
Total derivative liabilities	$	3	$	12	$	15

(1) Current derivative assets are presented in other current assets in Virginia Power’s Consolidated Balance Sheets.

(2) Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets.

(3) Current derivative liabilities are presented in other current liabilities in Virginia Power’s Consolidated Balance Sheets.

(4) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.

PAGE 29

Derivatives in cash flow hedging relationships	Amount of Gain (Loss) Recognized in AOCI  on Derivatives (Effective Portion)(1)			Amount of Gain (Loss) Reclassified from AOCI to Income			Increase (Decrease) in Derivatives Subject to Regulatory Treatment(2)
(millions)
Three Months Ended September 30, 2010
Derivative Type and Location of Gains (Losses)
Commodity:
Purchased electric capacity				$	1
Total commodity	$	(1	)		1		$	(6	)
Interest rate(3)		—			—			1
Foreign currency(4)		—			—			—
Total	$	(1	)	$	1		$	(5	)
Three Months Ended September 30, 2009
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(2	)
Purchased electric capacity					1
Total commodity	$	—			(1	)	$	4
Interest rate(3)		(3	)		—			(18	)
Foreign currency(4)		—			—			(2	)
Total	$	(3	)	$	(1	)	$	(16	)
Nine Months Ended September 30, 2010
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(1	)
Purchased electric capacity					3
Total commodity	$	(2	)		2		$	(17	)
Interest rate(3)		(1	)		9			(23	)
Foreign currency(4)		—			—			(2	)
Total	$	(3	)	$	11		$	(42	)
Nine Months Ended September 30, 2009
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(8	)
Purchased electric capacity					4
Total commodity	$	(2	)		(4	)	$	9
Interest rate(3)		10			—			57
Foreign currency(4)		—			1			(2	)
Total	$	8		$	(3	)	$	64

(1) Amounts deferred into AOCI have no associated effect in Virginia Power’s Consolidated Statements of Income.

(2) Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power’s Consolidated Statements of Income.

(3) Amounts are recorded in interest and related charges in Virginia Power’s Consolidated Statements of Income.

(4) Amounts are recorded in electric fuel and other energy-related purchases in Virginia Power’s Consolidated Statements of Income.

PAGE 30

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months  Ended September 30,					Nine Months  Ended September 30,
Derivatives not designated as hedging instruments	2010		2009			2010			2009
(millions)
Derivative Type and Location of Gains (Losses)
Commodity(2)	$	22	$	(14	)	$	49		$	(152	)
Interest Rate(3)		—		—			(3	)		—
Total	$	22	$	(14	)	$	46		$	(152	)

(1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power’s Consolidated Statements of Income.

(2) Amounts are recorded in electric fuel and other energy-related purchases in Virginia Power’s Consolidated Statements of Income.

(3) Amounts are recorded in interest and related charges in Virginia Power’s Consolidated Statements of Income.

Note 11. Investments

Dominion

Rabbi Trust Securities

Marketable equity and debt securities and cash equivalents held in Dominion’s rabbi trusts and classified as trading totaled $86 million and $96 million at September 30, 2010 and December 31, 2009, respectively. Cost method investments held in Dominion’s rabbi trusts totaled $18 million and $17 million at September 30, 2010 and December 31, 2009, respectively.

Decommissioning Trust Securities

Dominion holds marketable equity and debt securities (classified as available-for-sale), cash equivalents and cost method investments in nuclear decommissioning trust funds in order to fund future decommissioning costs for its nuclear plants. Dominion’s decommissioning trust funds are summarized below.

	Amortized Cost		Total  Unrealized Gains(1)		Total  Unrealized Losses(1)			Fair Value
(millions)
September 30, 2010
Marketable equity securities	$	1,187	$	378	$	—		$	1,565
Marketable debt securities:
Corporate bonds		323		23		—			346
U.S. Treasury securities and agency debentures		415		19		—			434
State and municipal		209		17		(2	)		224
Other		20		1		—			21
Cost method investments		108		—		—			108
Cash equivalents and other(2)		47		—		—			47
Total	$	2,309	$	438	$	(2	)(3)	$	2,745
December 31, 2009
Marketable equity securities	$	1,191	$	338	$	—		$	1,529
Marketable debt securities:
Corporate bonds		241		13		(1	)		253
U.S. Treasury securities and agency debentures		281		13		(1	)		293
State and municipal		371		21		(3	)		389
Other		4		—		—			4
Cost method investments		97		—		—			97
Cash equivalents and other(2)		60		—		—			60
Total	$	2,245	$	385	$	(5	)(3)	$	2,625

(1) Included in AOCI and the decommissioning trust regulatory liability.

(2) At September 30, 2010 and December 31, 2009, reflects $57 million and $11 million, respectively, related to net pending sales and purchases of securities.

(3) The fair value of securities in an unrealized loss position was $88 million and $169 million at September 30, 2010 and December 31, 2009, respectively.

PAGE 31

The fair value of Dominion’s marketable debt securities (classified as available-for-sale) at September 30, 2010 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	79
Due after one year through five years		326
Due after five years through ten years		285
Due after ten years		335
Total	$	1,025

Presented below is selected information regarding Dominion’s marketable equity and debt securities.

	Three Months  Ended September 30,				Nine Months  Ended September 30,
	2010		2009		2010			2009
(millions)
Trading securities:
Net unrealized gain (loss)	$	—	$	8	$	(1	)	$	10
Available-for-sale securities:
Proceeds from sales		398		531		1,538	(1)		1,258
Realized gains(2)		16		113		89			174
Realized losses(2)		4		25		58			184

(1) The increase in proceeds primarily reflects changes in asset allocation and liquidation of positions in connection with changes in fund managers.

(2) Includes realized gains or losses recorded to the decommissioning trust regulatory liability.

Dominion recorded other-than-temporary impairment losses on investments as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2010			2009			2010			2009
(millions)
Total other-than-temporary impairment losses(1)	$	4		$	10		$	52		$	166
Losses recorded to decommissioning trust regulatory liability		(1	)		(6	)		(17	)		(76	)
Losses recognized in other comprehensive income (before taxes)		—			—			(2	)		(1	)
Net impairment losses recognized in earnings	$	3		$	4		$	33		$	89

(1) Amount includes other-than-temporary impairment losses for debt securities of $1 million for the three months ended September 30, 2010 and 2009, and $4 million and $9 million for the nine months ended September 30, 2010 and 2009, respectively.

Other Investments

In May 2010, using proceeds from the sale of the Appalachian E&P business, Dominion acquired $1.4 billion of short-term investments consisting of $700 million in time deposits and $700 million in Treasury Bills. As of September 30, 2010, $500 million of these investments are still held and are classified as other current assets on Dominion’s Consolidated Balance Sheet. There were no unrealized gains or losses for these investments as of September 30, 2010 and their amortized cost approximates fair value. Proceeds from the sale of these investments are expected to be used largely to pay the tax liability on the gain from the sale of the Appalachian E&P business.

PAGE 32

Virginia Power

Decommissioning Trust Securities

Virginia Power holds marketable equity and debt securities (classified as available-for-sale), cash equivalents and cost method investments in nuclear decommissioning trust funds in order to fund future decommissioning costs for its nuclear plants. Virginia Power’s decommissioning trust funds are summarized below.

	Amortized Cost		Total  Unrealized Gains(1)		Total  Unrealized Losses(1)			Fair Value
(millions)
September 30, 2010
Marketable equity securities	$	484	$	152	$	—		$	636
Marketable debt securities:
Corporate bonds		220		14		—			234
U.S. Treasury securities and agency debentures		154		4		—			158
State and municipal		81		5		—			86
Other		15		1		—			16
Cost method investments		108		—		—			108
Cash equivalents and other(2)		19		—		—			19
Total	$	1,081	$	176	$	—	(3)	$	1,257
December 31, 2009
Marketable equity securities	$	499	$	135	$	—		$	634
Marketable debt securities:
Corporate bonds		153		9		(1	)		161
U.S. Treasury securities and agency debentures		95		3		—			98
State and municipal		181		9		(1	)		189
Other		3		—		—			3
Cost method investments		97		—		—			97
Cash equivalents and other(2)		22		—		—			22
Total	$	1,050	$	156	$	(2	)(3)	$	1,204

(1) Included in AOCI and the decommissioning trust regulatory liability.

(2) At September 30, 2010 and December 31, 2009, reflects $34 million and $6 million, respectively, related to net pending sales and purchases of securities.

(3) The fair value of securities in an unrealized loss position was $62 million and $88 million at September 30, 2010, and December 31, 2009, respectively.

The fair value of Virginia Power’s marketable debt securities at September 30, 2010, by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	10
Due after one year through five years		167
Due after five years through ten years		170
Due after ten years		147
Total	$	494

PAGE 33

Presented below is selected information regarding Virginia Power’s marketable equity and debt securities.

	Three Months  Ended September 30,				Nine Months  Ended September 30,
	2010		2009		2010			2009
(millions)
Proceeds from sales	$	248	$	277	$	959	(1)	$	607
Realized gains(2)		6		60		43			83
Realized losses(2)		1		16		21			86

(1) The increase in proceeds primarily reflects changes in asset allocation and liquidation of positions in connection with changes in fund managers.

(2) Includes realized gains or losses recorded to the decommissioning trust regulatory liability.

Virginia Power recorded other-than-temporary impairment losses on investments as follows:

	Three Months  Ended September 30,						Nine Months  Ended September 30,
	2010			2009			2010			2009
(millions)
Total other-than-temporary impairment losses(1)	$	2		$	7		$	21		$	89
Losses recorded to decommissioning trust regulatory liability		(1	)		(6	)		(17	)		(76	)
Net impairment losses recognized in earnings	$	1		$	1		$	4		$	13

(1) Amount includes other-than-temporary impairment losses for debt securities of $1 million for the three months ended September 30, 2010 and 2009, and $2 million and $6 million for the nine months ended September 30, 2010 and 2009, respectively.

PAGE 34

Note 12. Regulatory Matters

Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 14 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009 and Note 12 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010.

Federal Energy Regulatory Commission

ODEC and NCEMC Complaint

In March 2010, ODEC and NCEMC filed a complaint against Virginia Power at FERC claiming that approximately $223 million in transmission costs related to specific projects were unjust, unreasonable and unduly discriminatory or preferential and should be excluded from Virginia Power’s transmission formula rate. ODEC and NCEMC requested that FERC establish procedures to determine the amount of costs for each applicable project that should be excluded from Virginia Power’s rates. In October 2010, FERC issued an order dismissing the complaint in part and established hearings and settlement procedures on the remaining part of the complaint. Virginia Power cannot predict the outcome of this proceeding.

Virginia Regulation

Virginia Fuel Expenses

In April 2010, Virginia Power filed its Virginia fuel factor application with the Virginia Commission. The application requested an annual decrease in fuel expense recovery of approximately $82 million for the period July 1, 2010 through June 30, 2011. The proposed fuel factor went into effect on July 1, 2010 on an interim basis. An evidentiary hearing on Virginia Power’s application was held in September 2010, and in October 2010, the Virginia Commission issued its final order approving the reduction in Virginia Power’s fuel factor as proposed in its application.

Generation Riders R and S

In June 2010, Virginia Power filed annual updates for Riders R and S with the Virginia Commission. The proposed revenue requirements under Riders R and S, effective April 1, 2011, for the rate year ending March 31, 2012 are approximately $86 million and $200 million, respectively. The ROE included in both rider filings is 12.3%, consistent with the terms of the rate settlement approved by the Virginia Commission in March 2010. In July 2010, the Commission issued an order with respect to Riders R and S, which adopted a placeholder ROE of 11.3% (not including the 100 basis point statutory enhancement) for use until the ROE is determined in the context of Virginia Power’s 2011 biennial review. The Commission scheduled public hearings on Riders R and S for December and November 2010, respectively.

PAGE 35

North Anna Power Station

Virginia Power is considering the construction of a third nuclear unit at a site located at North Anna, which Virginia Power owns along with ODEC. Virginia Power and ODEC have obtained an Early Site Permit for the North Anna site from the NRC. In November 2007, Virginia Power, along with ODEC, filed an application with the NRC for a COL to build and operate a new nuclear unit at North Anna. Following a competitive process, in May 2010, Virginia Power announced its selection of US-APWR technology for the potential third nuclear unit.

In June 2010, Virginia Power and ODEC amended the COL application to reflect the selection of the US-APWR technology. Virginia Power has a cooperative agreement with the DOE to share equally the cost of developing a COL that references the technology previously selected by Virginia Power. Funding is not available under the agreement for activities related to the US-APWR technology. DOE funding of program activities to close out the cooperative agreement will end during the fourth quarter of 2010, at which time the agreement will be terminated.

In July 2010, Virginia Power filed several applications for environmental permits that would be needed to support future construction and operation of a third nuclear unit at North Anna. Virginia Power expects to submit additional environmental permit applications during 2010.

Virginia Power has not yet committed to building a new nuclear unit at North Anna. If Virginia Power decides to build the new unit, it must first receive a COL from the NRC, the approval of the Virginia Commission and certain environmental permits and other approvals. The US-APWR design is currently undergoing a separate NRC certification process. Although the NRC completed its final supplemental environmental impact statement in March 2010 with respect to the November 2007 COL application, finding that there are no environmental impacts that would preclude issuing a COL, further safety and environmental review by the NRC is now taking place as a result of the subsequent selection of the US-APWR technology.

The NRC is required to conduct a hearing in all COL proceedings. In August 2008, the ASLB of the NRC permitted BREDL to intervene in the proceeding. All of BREDL’s previous contentions in this proceeding have been dismissed, but the ASLB set a deadline of October 4, 2010 for the filing of new proposed contentions based on new information contained in the June 2010 amendment to the COL application. BREDL timely submitted two new contentions that it seeks to litigate. No other persons sought to intervene in the proceeding. Virginia Power’s response to BREDL’s new proposed contentions is expected to be filed in the fourth quarter of 2010. The ASLB will thereafter rule on the admissibility of the proposed contentions. Absent additional admitted contentions, the mandatory NRC hearing will be uncontested with respect to other issues.

North Carolina Base Rate and Fuel Cases

In February 2010, in preparation for the end of the five-year base rate moratorium, Virginia Power filed an application to increase its base and fuel rates. Virginia Power’s application included a proposal to recover more of its purchased power energy costs through fuel rates, which are adjusted annually, instead of being recovered in base rates. In August 2010, Virginia Power filed its annual application for a change in its fuel rates, which updated the fuel application of February 2010 to reflect a proposed decrease of approximately $28 million when compared to current fuel rates. Also in August 2010, Virginia Power updated its base rate application to seek a $27 million increase.

In September 2010 all parties to the base rate and fuel case except one, which does not oppose the settlement, filed an Agreement and Stipulation of Settlement and requested approval from the North Carolina Commission. The stipulation provides for an increase in base revenues of approximately $8 million and a decrease in combined fuel revenues of approximately $32 million when compared to revenues produced from current rates. In addition, the stipulation entails a recovery through fuel rates of 85% of the net energy costs of power purchases from both PJM and other wholesale suppliers and from the non-utility generators subject to economic dispatch that do not provide actual cost data. An evidentiary hearing was conducted in October 2010 and the North Carolina Commission is expected to issue an order on the stipulation in the base rate and fuel case proceeding during the fourth quarter of 2010. Should the North Carolina Commission approve the stipulation, the new rates are anticipated to go into effect on January 1, 2011.

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Ohio Pipeline Infrastructure Replacement

In October 2008, the Ohio Commission approved cost recovery for an initial five-year period of East Ohio’s 25-year PIR program to replace approximately 20% of its 21,000-mile pipeline system. In August 2010, East Ohio filed its second annual application to adjust the cost recovery charge associated with its PIR program for actual costs and a return related to investments made through June 30, 2010. The application reflected a revenue requirement of approximately $28 million. In October 2010, East Ohio and the staff of the Ohio Commission filed a settlement agreement with the Commission reflecting a revenue requirement of approximately $27 million. Other interested parties to the case neither supported nor objected to the settlement agreement.

Note 13. Variable Interest Entities

As discussed in Note 16 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, certain variable pricing terms in some of the Companies’ long-term power and capacity contracts cause them to be considered variable interests in the counterparties.

Virginia Power has long-term power and capacity contracts with four non-utility generators with an aggregate generation capacity of approximately 947 MW at September 30, 2010. These contracts contain certain variable pricing mechanisms in the form of partial fuel reimbursement that Virginia Power considers to be variable interests. After an evaluation of the information provided by these entities, Virginia Power was unable to determine whether they were VIEs. However, the information they provided, as well as Virginia Power’s knowledge of generation facilities in Virginia, enabled Virginia Power to conclude that, if they were VIEs, it would not be the primary beneficiary. This conclusion reflects Virginia Power’s determination that its variable interests do not convey the power to direct the most significant activities that impact the economic performance of the entity during the remaining terms of Virginia Power’s contracts and for the years the entities are expected to operate after its contractual relationships expire. The contracts expire at various dates ranging from 2015 to 2021. Virginia Power is not subject to any risk of loss from these potential VIEs other than its remaining purchase commitments which totaled $1.6 billion as of September 30, 2010. Virginia Power paid $53 million and $52 million for electric capacity and $46 million and $24 million for electric energy to these entities for the three months ended September 30, 2010 and 2009, respectively. Virginia Power paid $160 million and $156 million for electric capacity and $120 million and $90 million for electric energy to these entities for the nine months ended September 30, 2010 and 2009, respectively.

Virginia Power purchased shared services from DRS, an affiliated VIE, of approximately $104 million and $108 million for the three months ended September 30, 2010 and 2009, respectively, and $352 million and $307 million for the nine months ended September 30, 2010 and 2009, respectively. Virginia Power determined that it is not the most closely associated entity with DRS and therefore not the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Virginia Power. Virginia Power has no obligation to absorb more than its allocated share of DRS costs.

Note 14. Significant Financing Transactions

Credit Facilities and Short-term Debt

Dominion and Virginia Power use short-term debt to fund working capital requirements, as a bridge to long-term debt financing and as bridge financing for acquisitions, if applicable. 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. In addition, Dominion utilizes cash and letters of credit to fund collateral requirements under its commodities hedging program. Collateral requirements are impacted by commodity prices, hedging levels, Dominion’s credit quality and the credit quality of its counterparties.

Dominion and Virginia Power replaced certain of their existing credit facilities in September 2010, as noted below.

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At September 30, 2010, Dominion’s commercial paper, bank loans and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:

	Facility Limit		Outstanding Commercial Paper		Outstanding Bank Borrowings		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Three-year joint revolving credit facility(1)	$	3,000	$	100	$	—	$	145	$	2,755
Three-year joint revolving credit facility(2)		500		—		—		—		500
Five-year Dominion bilateral facility(3)		200		—		—		21		179
Total	$	3,700	$	100	$	—	$	166	$	3,434

(1) This credit facility was entered into in September 2010 and terminates in September 2013. This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion of letters of credit. Virginia Power’s current sub-limit under this credit facility is $1 billion, which can be increased or decreased multiple times per year.

(2) This credit facility was entered into in September 2010 and terminates in September 2013. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power’s current sub-limit under this credit facility is $250 million, which can be increased or decreased multiple times per year.

(3) This facility was entered into in December 2005 and terminates in December 2010. This facility can be used to support bank borrowings, commercial paper and letter of credit issuances.

In addition to the credit facility commitments disclosed above, Virginia Power also has a three-year $120 million credit facility that was entered into in September 2010. The facility, which terminates in September 2013, supports certain tax-exempt financings of Virginia Power.

Long-term Debt

In September 2010, Dominion issued $250 million of 2.25% senior notes that mature in 2015. The proceeds were used for general corporate purposes and to pre-fund Dominion’s projected fourth quarter 2010 capital needs.

In September 2010, Virginia Power issued $300 million of 3.45% senior notes that mature in 2022. The proceeds were used for general corporate purposes, including the pre-funding of fourth quarter 2010 capital needs, and the repayment of short-term debt, including intercompany debt owed to Dominion.

Dominion repaid $414 million of long-term debt during the nine months ended September 30, 2010.

Convertible Securities

At September 30, 2010, Dominion had $202 million of outstanding contingent convertible senior notes that are convertible by holders into a combination of cash and shares of Dominion’s common stock under certain circumstances. The conversion feature requires that the principal amount of each note be repaid in cash, while amounts payable in excess of the principal amount will be paid in common stock. The conversion rate is subject to adjustment upon certain events such as subdivisions, splits, combinations of common stock or the issuance to all common stock holders of certain common stock rights, warrants or options and certain dividend increases. As of September 30, 2010, the conversion rate has been adjusted, primarily due to individual dividend payments above the level paid at issuance, to 28.4113 shares of common stock per $1,000 principal amount of senior notes, which represents a conversion price of $35.20.

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During the first three quarters of 2010, the senior notes were not eligible for conversion. However, as of September 30, 2010, the closing price of Dominion’s common stock was equal to $42.24 per share or higher for at least 20 out of the last 30 consecutive trading days; therefore, the senior notes are eligible for conversion during the fourth quarter of 2010.

Issuance of Common Stock

During the nine months ended September 30, 2010, Dominion issued 2.1 million shares of common stock and received cash proceeds of $66 million. The shares issued and cash proceeds received during the nine months ended September 30, 2010 were through Dominion Direct®, employee savings plans and the exercise of employee stock options. In February 2010, Dominion began purchasing its common stock on the open market with proceeds received through Dominion Direct^® and employee savings plans, rather than issuing additional new common shares.

In March, September and October 2010, Virginia Power issued 14,600, 6,700 and 8,900 shares of its common stock to Dominion for approximately $433 million, $203 million and $277 million, respectively. The proceeds were used to pay down short-term demand note borrowings from Dominion.

Repurchase of Common Stock

In March 2010, Dominion began repurchasing common shares in anticipation of proceeds from the sale of its Appalachian E&P operations. During the nine months ended September 30, 2010, Dominion repurchased 21.4 million shares of its common stock for approximately $900 million. As of September 30, 2010, Dominion does not intend to repurchase any additional common shares with proceeds received from the sale.

Note 15. Commitments and Contingencies

Other than the following matters, there have been no significant developments regarding the commitments and contingencies disclosed in Note 23 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, or Note 15 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010, respectively, nor have any significant new matters arisen during the three months ended September 30, 2010.

Guarantees

Dominion

At September 30, 2010, Dominion had issued $131 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of September 30, 2010, Dominion’s exposure under these guarantees was $54 million, primarily related to certain reserve requirements associated with non-recourse financing.

Dominion also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. To the extent that a liability subject to a guarantee has been incurred by one of Dominion’s consolidated subsidiaries, that liability is included in Dominion’s Consolidated Financial Statements. Dominion is not required to recognize liabilities for guarantees issued on behalf of its subsidiaries unless it becomes probable that it will have to perform under the guarantees. Terms of the guarantees typically end once obligations have been paid. Dominion currently believes it is unlikely that it would be required to perform or otherwise incur any losses associated with guarantees of its subsidiaries’ obligations.

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At September 30, 2010, Dominion had issued the following subsidiary guarantees:

	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	126	$	126
Commodity transactions(3)		3,001		231
Lease obligation for power generation facility(4)		784		784
Nuclear obligations(5)		231		52
Other(6)		500		139
Total	$	4,642	$	1,332

(1) Represents the estimated portion of the guarantee’s stated limit that is utilized as of September 30, 2010 based upon prevailing economic conditions and fact patterns specific to each guarantee arrangement. For those guarantees related to obligations that are recorded as liabilities by Dominion’s subsidiaries, the value includes the recorded amount.

(2) Guarantees of debt of certain DEI subsidiaries. In the event of default by the subsidiaries, Dominion would be obligated to repay such amounts.

(3) Guarantees related to energy trading and marketing activities and other commodity commitments of certain subsidiaries. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and other energy-related commodities and services. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion would be obligated to satisfy such obligation. Dominion and its subsidiaries receive similar guarantees as collateral for credit extended to others. The value provided includes certain guarantees that do not have stated limit amounts.

(4) Guarantee of a DEI subsidiary’s leasing obligation for Fairless.

(5) Guarantees related to certain DEI subsidiaries’ potential retrospective premiums that could be assessed if there is a nuclear incident under Dominion’s nuclear insurance programs and guarantees for a DEI subsidiary’s and Virginia Power’s commitment to buy nuclear fuel. Excludes Dominion’s agreement to provide up to $150 million and $60 million to two DEI subsidiaries to pay the operating expenses of Millstone and Kewaunee, respectively, in the event of a prolonged outage, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations.

(6) Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries’ obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower.

Virginia Power

As of September 30, 2010, Virginia Power had issued $16 million of guarantees primarily to support tax-exempt debt issued through conduits. No significant amounts related to these guarantees have been recorded.

Spent Nuclear Fuel

In August 2010, Dominion and the federal government reached a settlement resolving Dominion’s claims for damages incurred at Kewaunee prior to December 31, 2008 in connection with the government’s failure to commence accepting spent nuclear fuel. The approximately $21 million settlement payment was received in September 2010 and was credited to the receivable from the government that Dominion recognized as of June 30, 2010 for spent nuclear fuel-related costs. Other lawsuits filed by Dominion and Virginia Power against the DOE requesting damages incurred for spent nuclear fuel-related costs at Millstone, Surry and North Anna remain pending. The Companies will continue to manage their spent nuclear fuel until it is accepted by the DOE.

Surety Bonds and Letters of Credit

As of September 30, 2010, Dominion had purchased $87 million of surety bonds, including $39 million at Virginia Power, and authorized the issuance of standby letters of credit by financial institutions of $166 million, including $94 million at Virginia Power, to facilitate commercial transactions by its subsidiaries with third parties. Under the terms of the surety bonds, the Companies are obligated to indemnify the respective surety bond company for any amounts paid.

Environmental Matters

The EPA has finalized rules establishing a new 1-hour NAAQS for NO₂ (January 2010) and a new 1-hour NAAQS for SO₂ (June 2010), which could require additional NO_X and SO₂ controls in certain areas where the Companies operate. Until the states have developed implementation plans for these standards, the impact on Dominion’s or Virginia Power’s facilities that emit NO_X and SO₂ is uncertain. However, based on a preliminary assessment, Dominion has determined that the new 1-hour SO₂ NAAQS will likely

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require significant future capital expenditures at State Line, and has recorded an impairment charge on this facility as detailed in Note 9. In January 2010, the EPA proposed a new, more stringent NAAQS for ozone and in July 2010, the EPA announced a proposed new rule, called the “Transport Rule,” which will eventually replace the current “Clean Air Interstate Rule” and as proposed requires significant reductions in SO₂ and NO_X emissions. Until this rulemaking is complete and states have developed implementation plans for the new standards, it is not possible to determine the impact on Dominion’s or Virginia Power’s facilities that emit NO_X and SO₂. The Companies cannot currently predict whether or to what extent the new rule will ultimately require additional controls.

Water

In October 2007, the VSWCB issued a VPDES permit for North Anna. The BREDL, and other persons, appealed the VSWCB’s decision to the Richmond Circuit Court, challenging several permit provisions related to North Anna’s discharge of cooling water. In February 2009, the court ruled that the VSWCB was required to regulate the thermal discharge from North Anna into the waste heat treatment facility. Virginia Power filed a motion for reconsideration with the court in February 2009, which was denied. The final order was issued by the court in September 2009. The court’s order allows North Anna to continue to operate pursuant to the currently issued VPDES permit. In October 2009, Virginia Power filed a Notice of Appeal of the court’s Order with the Richmond Circuit Court, initiating the appeals process to the Virginia Court of Appeals. In June 2010, the Virginia Court of Appeals reversed the Richmond Circuit Court’s September 2009 order. The Virginia Court of Appeals held that the lower court had applied the wrong standard of review, and that the VSWCB’s determination not to regulate the station’s thermal discharge into the waste heat treatment facility was lawful. In July 2010, BREDL and the other original appellants filed a petition for appeal to the Supreme Court of Virginia requesting that it review the Court of Appeals’ decision.

An administrative hearing with the Connecticut Department of Environmental Protection to renew the National Pollutant Discharge Elimination System Permit for Millstone, which allows Millstone to return water used in the generating process to its source, was completed in February 2009. In September 2010, the permit was reissued under the Clean Water Act. The conditions of the permit require an evaluation of control technologies that could result in additional expenditures in the future, however Dominion cannot currently predict the outcome of this evaluation. In October 2010, the permit issuance was appealed to the state court by a private plaintiff. The permit is expected to remain in effect during the appeal.

Note 16. Credit Risk

Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition, collateral requirements and the use of standardized agreements that facilitate the netting of cash flows associated with a single counterparty. In addition, counterparties may make available collateral, including letters of credit or cash held as margin deposits, as a result of exceeding agreed-upon credit limits, or may be required to prepay the transaction. Dominion and Virginia Power maintain a provision for credit losses based on factors surrounding the credit risk of their customers, historical trends and other information. Management believes, based on credit policies and the provision for credit losses, that it is unlikely that a material adverse effect on financial position, results of operations or cash flows would occur as a result of counterparty nonperformance.

Dominion

As a diversified energy company, Dominion transacts primarily with major companies in the energy industry and with commercial and residential energy consumers. These transactions principally occur in the Northeast, mid-Atlantic and Midwest regions of the U.S. and Texas. Dominion does not believe that this geographic concentration contributes significantly to its overall exposure to credit risk. In addition, as a result of its large and diverse customer base, Dominion is not exposed to a significant concentration of credit risk for receivables arising from electric and gas utility operations.

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Dominion’s exposure to credit risk is concentrated primarily within its energy marketing and price risk management activities, as Dominion transacts with a smaller, less diverse group of counterparties and transactions may involve large notional volumes and potentially volatile commodity prices. Energy marketing and price risk management activities include trading of energy-related commodities, marketing of merchant generation output, structured transactions and the use of financial contracts for enterprise-wide hedging purposes. Gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of collateral. At September 30, 2010, Dominion’s gross credit exposure totaled $756 million. After the application of collateral, credit exposure is reduced to $676 million. Of this amount, investment grade counterparties, including those internally rated, represented 86%. One counterparty exposure is greater than 10% of Dominion’s total exposure, representing 13%, and is a large financial institution rated investment grade.

The majority of Dominion’s derivative instruments contain credit-related contingent provisions. These provisions require Dominion to provide collateral upon the occurrence of specific events, primarily a credit downgrade. If the credit-related contingent features underlying these instruments that are in a liability position and not fully collateralized with cash were fully triggered as of September 30, 2010 and December 31, 2009, Dominion would have been required to post an additional $90 million and $36 million, respectively, of collateral to its counterparties. The collateral that would be required to be posted includes the impacts of any offsetting asset positions and any amounts already posted for derivatives, non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. Dominion had posted $52 million in collateral, including $19 million of letters of credit at September 30, 2010 and $62 million in collateral, including $48 million of letters of credit at December 31, 2009, related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. The collateral posted includes any amounts paid related to non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. The aggregate fair value of all derivative instruments with credit-related contingent provisions that are in a liability position and not fully collateralized with cash as of September 30, 2010 and December 31, 2009 is $196 million and $181 million, respectively, and does not include the impact of any offsetting asset positions. See Note 10 for further information about derivative instruments.

Virginia Power

Virginia Power sells electricity and provides distribution and transmission services to customers in Virginia and northeastern North Carolina. Management believes that this geographic concentration risk is mitigated by the diversity of Virginia Power’s customer base, which includes residential, commercial and industrial customers, as well as rural electric cooperatives and municipalities. Credit risk associated with trade accounts receivable from energy consumers is limited due to the large number of customers. Virginia Power’s exposure to potential concentrations of credit risk results primarily from sales to wholesale customers. Virginia Power’s gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of collateral. At September 30, 2010, Virginia Power’s gross credit exposure totaled $18 million. After the application of collateral, credit exposure is reduced to $6 million. Of this amount, investment grade counterparties, including those internally rated, represented $2 million, and no single counterparty, whether investment grade or non-investment grade, exceeded $3 million of exposure.

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Note 17. Related Party Transactions

Virginia Power engages in related party transactions primarily with other Dominion subsidiaries (affiliates). Virginia Power’s receivable and payable balances with affiliates are settled based on contractual terms or on a monthly basis, depending on the nature of the underlying transactions. Virginia Power is included in Dominion’s consolidated federal income tax return and participates in certain Dominion benefit plans. A discussion of other significant related party transactions follows.

Transactions with Affiliates

Virginia Power transacts with affiliates for certain quantities of natural gas and other commodities in the ordinary course of business. Virginia Power also enters into certain commodity derivative contracts with affiliates. Virginia Power uses these contracts, which are principally comprised of commodity swaps, to manage commodity price risks associated with purchases of natural gas. Virginia Power designates the majority of these contracts as cash flow hedges for accounting purposes.

DRS provides accounting, legal, finance and certain administrative and technical services to Virginia Power.

Presented below are significant Virginia Power transactions with DRS and other affiliates:

	Three Months  Ended September 30,				Nine Months  Ended September 30,
	2010		2009		2010		2009
(millions)
Commodity purchases from affiliates	$	150	$	109	$	306	$	263
Services provided by affiliates		106		109		355		310

Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. Virginia Power’s outstanding borrowings, net of repayments, under the Dominion money pool for its nonregulated subsidiaries totaled $59 million and $2 million, as of September 30, 2010 and December 31, 2009, respectively. Virginia Power’s short-term demand note borrowings from Dominion were $205 million at September 30, 2010, and there were no such short-term demand note borrowings at December 31, 2009.

In March, September and October 2010, Virginia Power issued 14,600, 6,700 and 8,900 shares of its common stock to Dominion for approximately $433 million, $203 million and $277 million, respectively. The proceeds were used to pay down short-term demand note borrowings from Dominion.

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Note 18. Employee Benefit Plans

The components of the provision for net periodic benefit cost (credit) were as follows:

	Pension Benefits						Other Postretirement Benefits
	2010			2009			2010			2009
(millions)
Three Months Ended September 30,
Service cost	$	25		$	26		$	13		$	15
Interest cost		66			63			26			24
Expected return on plan assets		(103	)		(101	)		(17	)		(14	)
Amortization of prior service cost (credit)		1			1			(2	)		(1	)
Amortization of net loss		15			9			3			7
Net periodic benefit cost (credit)	$	4		$	(2	)	$	23		$	31
Nine Months Ended September 30,
Service cost	$	77		$	79		$	41		$	45
Interest cost		200			188			76			74
Expected return on plan assets		(308	)		(304	)		(52	)		(42	)
Amortization of prior service cost (credit)		3			3			(5	)		(5	)
Amortization of net loss		45			28			9			22
Settlements and curtailments(1)		84			2			37			—
Special termination benefits(2)		10			2			1			—
Net periodic benefit cost (credit)	$	111		$	(2	)	$	107		$	94

(1) Relates to the sale of Peoples and a workforce reduction program.

(2) Represents a one-time special termination benefit for certain employees in connection with a workforce reduction program.

Employer Contributions

During the nine months ended September 30, 2010, Dominion contributed $250 million to its defined benefit pension plans. Virginia Power’s portion of this contribution was $119 million. Dominion made no contributions to its other postretirement benefit plans during the nine months ended September 30, 2010, but expects to contribute approximately $56 million, of which Virginia Power’s portion is expected to be $35 million, to its other postretirement benefit plans through Voluntary Employees’ Beneficiary Associations during the remainder of 2010.

Note 19. Operating Segments

Dominion and Virginia Power are organized primarily on the basis of products and services sold in the U.S. A description of the operations included in the Companies’ primary operating segments is as follows:

Primary Operating Segment	Description of Operations	Dominion	Virginia Power
DVP	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
	Nonregulated retail energy marketing (electric and gas)	X
Dominion Generation	Regulated electric fleet	X	X
	Merchant electric fleet	X
Dominion Energy	Gas transmission and storage	X
	Gas distribution	X
	LNG import and storage	X
	Producer services	X

In addition to the operating segments above, the Companies also report a Corporate and Other segment.

The Corporate and Other Segment of Dominion includes its corporate, service company and other functions (including unallocated debt) and certain specific items that are not included in profit measures evaluated by executive management in assessing segment performance or allocating resources among the segments.

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In the nine months ended September 30, 2010, Dominion reported after-tax net benefits of $905 million for specific items in the Corporate and Other segment, with $1.1 billion of these net benefits attributable to its operating segments. In the nine months ended September 30, 2009, Dominion reported after-tax net expenses of $272 million for specific items in the Corporate and Other segment, with $239 million of these net expenses attributable to its operating segments.

The net benefits for specific items in 2010 primarily related to the impact of the following items:

• A $2.5 billion ($1.4 billion after-tax) benefit resulting from the gain on the sale of substantially all of Dominion’s Appalachian E&P operations net of charges related to the divestiture, attributable to Dominion Energy; partially offset by

• A $338 million ($206 million after-tax) charge primarily reflecting severance pay and other benefits related to a workforce reduction program, attributable to:

• DVP ($67 million after-tax);

• Dominion Energy ($24 million after-tax); and

• Dominion Generation ($115 million after-tax);

• A $134 million ($147 million after-tax) loss from the discontinued operations of Peoples primarily reflecting a net loss on the sale, attributable to the Corporate and Other segment; and

• A $163 million ($95 million after-tax) impairment charge at State Line to reflect the estimated fair value of the power station, attributable to Dominion Generation.

The net expenses for specific items in 2009 primarily related to the impact of the following items:

• A $455 million ($281 million after-tax) ceiling test impairment charge related to the carrying value of Dominion’s E&P properties, attributable to Dominion Energy; partially offset by

• A $103 million ($62 million after-tax) reduction in other operations and maintenance expense due to a downward revision in the nuclear decommissioning ARO for a power station unit that is no longer in service, attributable to Dominion Generation.

The Corporate and Other Segment of Virginia Power primarily includes certain specific items that are not included in profit measures evaluated by executive management in assessing segment performance or allocating resources among the segments. In the nine months ended September 30, 2010 and 2009, Virginia Power reported after-tax net expenses of $149 million and $6 million, respectively, for specific items attributable to its operating segments in the Corporate and Other segment.

The net expenses for specific items in 2010 primarily related to the impact of the following:

• A $202 million ($123 million after-tax) charge primarily reflecting severance pay and other benefits related to a workforce reduction program, attributable to:

• DVP ($63 million after-tax); and

• Dominion Generation ($60 million after-tax).

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The following table presents segment information pertaining to Dominion’s operations:

	DVP		Dominion Generation		Dominion Energy		Corporate and Other			Adjustments/ Eliminations			Consolidated Total
(millions)
Three Months Ended September 30,
2010
Total revenue from external customers	$	907	$	2,312	$	367	$	(6	)	$	370		$	3,950
Intersegment revenue		16		114		339		172			(641	)		—
Total operating revenue		923		2,426		706		166			(271	)		3,950
Net income (loss) attributable to Dominion		107		487		92		(111	)		—			575
2009
Total revenue from external customers	$	666	$	2,261	$	405	$	(11	)	$	309		$	3,630
Intersegment revenue		20		115		309		181			(625	)		—
Total operating revenue		686		2,376		714		170			(316	)		3,630
Loss from discontinued operations, net of tax		—		—		—		(41	)		—			(41	)
Net income (loss) attributable to Dominion		95		459		93		(53	)		—			594
Nine Months Ended September 30,
2010
Total revenue from external customers	$	2,697	$	6,121	$	1,667	$	28		$	938		$	11,451
Intersegment revenue		123		324		906		571			(1,924	)		—
Total operating revenue		2,820		6,445		2,573		599			(986	)		11,451
Loss from discontinued operations, net of tax		—		—		—		(147	)		—			(147	)
Net income attributable to Dominion		333		1,088		353		736			—			2,510
2009
Total revenue from external customers	$	2,315	$	6,542	$	1,898	$	(33	)	$	900		$	11,622
Intersegment revenue		103		276		950		531			(1,860	)		—
Total operating revenue		2,418		6,818		2,848		498			(960	)		11,622
Loss from discontinued operations, net of tax		—		—		—		(47	)		—			(47	)
Net income (loss) attributable to Dominion		292		1,098		372		(466	)		—			1,296

Intersegment sales and transfers for Dominion are based on contractual arrangements and may result in intersegment profit or loss that is eliminated in consolidation.

PAGE 46

The following table presents segment information pertaining to Virginia Power’s operations:

	DVP		Dominion Generation		Corporate and Other			Consolidated Total
(millions)
Three Months Ended September 30,
2010
Operating revenue	$	453	$	1,658	$	—		$	2,111
Net income (loss)		102		286		(8	)		380
2009
Operating revenue	$	374	$	1,564	$	—		$	1,938
Net income (loss)		83		233		(1	)		315
Nine Months Ended September 30,
2010
Operating revenue	$	1,253	$	4,308	$	—		$	5,561
Net income (loss)		300		589		(147	)		742
2009
Operating revenue	$	1,107	$	4,365	$	—		$	5,472
Net income (loss)		249		426		(7	)		668

PAGE 47

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS

OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

MD&A discusses Dominion’s and Virginia Power’s results of operations and general financial condition. MD&A should be read in conjunction with the Companies’ Consolidated Financial Statements.

Contents of MD&A

MD&A consists of the following information:

• Forward-Looking Statements

• Accounting Matters

• Dominion

• Results of Operations

• Segment Results of Operations

• Virginia Power

• Results of Operations

• Segment Results of Operations

• Liquidity and Capital Resources

• Future Issues and Other Matters

Forward-Looking Statements

This report contains statements concerning Dominion’s and Virginia Power’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 such words as “anticipate,” “estimate,” “forecast,” “expect,” “believe,” “should,” “could,” “plan,” “may,” “target” or other similar words.

Dominion and Virginia Power make forward-looking statements with full knowledge that risks and uncertainties exist that may cause actual results to differ materially from predicted results. Factors that may cause actual results to differ are often presented with the forward-looking statements themselves. Additionally, other factors may cause actual results to differ materially from those indicated in any forward-looking statement. These factors include but are not limited to:

• Unusual weather conditions and their effect on energy sales to customers and energy commodity prices;

• Extreme weather events, including hurricanes, high winds and severe storms, that can cause outages and property damage to facilities;

• Federal, state and local legislative and regulatory developments;

• Changes to federal, state and local environmental laws and regulations, including those related to climate change, the tightening of emission or discharge limits for GHGs and other emissions, more extensive permitting requirements and the regulation of additional substances;

• Cost of environmental compliance, including those costs related to climate change;

• Risks associated with the operation of nuclear facilities;

• Unplanned outages of the Companies’ generation facilities;

• Fluctuations in energy-related commodity prices and the effect these could have on Dominion’s earnings and Dominion’s and Virginia Power’s liquidity position and the underlying value of their assets;

• Counterparty credit risk;

• Capital market conditions, including the availability of credit and the ability to obtain financing on reasonable terms;

• Risks associated with Virginia Power’s membership and participation in PJM related to obligations created by the default of other participants;

• Price risk due to investments held in nuclear decommissioning trusts by Dominion and Virginia Power and in benefit plan trusts by Dominion;

• Fluctuations in interest rates;

• Changes in federal and state tax laws and regulations;

• Changes in rating agency requirements or credit ratings and their effect on availability and cost of capital;

• Changes in financial or regulatory accounting principles or policies imposed by governing bodies;

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• Employee workforce factors including collective bargaining agreements and labor negotiations with union employees;

• The risks of operating businesses in regulated industries that are subject to changing regulatory structures;

• Receipt of approvals for, and timing of, closing dates for acquisitions and divestitures;

• Changes in rules for RTOs and independent system operators in which Dominion and Virginia Power participate, including changes in rate designs and new and evolving capacity models;

• Political and economic conditions, including the threat of domestic terrorism, inflation and deflation;

• Changes to regulated electric rates collected by Virginia Power and regulated gas distribution, transportation and storage rates, including LNG storage, collected by Dominion;

• Timing and receipt of regulatory approvals necessary for planned construction or expansion projects;

• The inability to complete planned construction projects within the terms and time frames initially anticipated; and

• Adverse outcomes in litigation matters.

Additionally, other risks that could cause actual results to differ from predicted results are set forth in Item 1A. Risk Factors in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009.

Dominion’s and Virginia Power’s forward-looking statements are based on beliefs and assumptions using information available at the time the statements are made. The Companies caution the reader not to place undue reliance on their forward-looking statements because the assumptions, beliefs, expectations and projections about future events may, and often do, differ materially from actual results. Dominion and Virginia Power undertake no obligation to update any forward-looking statement to reflect developments occurring after the statement is made.

Accounting Matters

Critical Accounting Policies and Estimates

As of September 30, 2010, there have been no significant changes with regard to the critical accounting policies and estimates disclosed in MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, other than the accounting for gas and oil operations, which is no longer a critical accounting policy due to the sale of substantially all of Dominion’s Appalachian E&P operations. The other policies disclosed included the accounting for regulated operations, AROs, income taxes, derivative contracts and other instruments at fair value, goodwill and long-lived asset impairment testing, employee benefit plans and unbilled revenue.

Other

See Note 9 to Dominion’s and Virginia Power’s Consolidated Financial Statements for information on fair value measurements.

Dominion

Results of Operations

Presented below is a summary of Dominion’s consolidated results:

	2010		2009		$ Change
(millions, except EPS)
Third Quarter
Net income attributable to Dominion	$	575	$	594	$	(19	)
Diluted EPS		0.98		1.00		(0.02	)
Year-To-Date
Net income attributable to Dominion	$	2,510	$	1,296	$	1,214
Diluted EPS		4.23		2.19		2.04

Overview

Third Quarter 2010 vs. 2009

Net income attributable to Dominion decreased by 3%. Unfavorable drivers include lower margins from merchant generation operations, the absence of earnings from disposed Appalachian E&P operations, lower nuclear decommissioning trust earnings and an increase in Dominion’s interim income tax provision. Favorable drivers include the impact of warmer weather on electric utility operations and the absence of a loss from the discontinued operations of Peoples.

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Year-to-Date 2010 vs. 2009

Net income attributable to Dominion increased by $1.2 billion. Favorable drivers include a gain on the sale of Dominion’s Appalachian E&P operations, lower ceiling test impairment charges related to these properties and the impact of favorable weather on electric utility operations. Unfavorable drivers include charges related to a workforce reduction program, a loss on the sale of Peoples, lower margins from merchant generation operations and an impairment charge related to State Line.

Analysis of Consolidated Operations

Presented below are selected amounts related to Dominion’s results of operations:

	Third Quarter								Year-To-Date
	2010		2009			$ Change			2010			2009			$ Change
(millions)
Operating revenue	$	3,950	$	3,630		$	320		$	11,451		$	11,622		$	(171	)
Electric fuel and other energy-related purchases		1,180		1,072			108			3,164			3,211			(47	)
Purchased electric capacity		116		96			20			333			309			24
Purchased gas		367		281			86			1,550			1,639			(89	)
Net revenue		2,287		2,181			106			6,404			6,463			(59	)
Other operations and maintenance		788		713			75			2,709			2,632			77
Depreciation, depletion and amortization		263		274			(11	)		794			824			(30	)
Other taxes		117		106			11			405			366			39
Gain on sale of Appalachian E&P operations		—		—			—			2,467			—			2,467
Other income		63		128			(65	)		109			136			(27	)
Interest and related charges		229		217			12			600			656			(56	)
Income tax expense		374		360			14			1,803			766			1,037
Loss from discontinued operations		—		(41	)		41			(147	)		(47	)		(100	)

An analysis of Dominion’s results of operations follows:

Third Quarter 2010 vs. 2009

Net revenue increased 5%, primarily reflecting:

• A $198 million increase from electric utility operations primarily due to an increase in cooling degree days ($127 million), the impact of Riders C1 and C2, R, S and T ($79 million) and an increase in ancillary services revenue ($31 million) primarily reflecting higher regulation and operating reserves revenue received from PJM, partially offset by a $39 million decrease due to the impact of unfavorable economic conditions on customer usage and other factors;

• A $25 million increase from regulated gas distribution operations primarily reflecting increased rider revenue associated with the recovery of deferred bad debt expense ($11 million) and an increase in base rates ($10 million); and

• A $19 million increase from producer services primarily related to favorable price changes on economic hedging positions partially offset by lower physical margins, all associated with natural gas aggregation, marketing and trading activities.

These increases were partially offset by:

• A $73 million decrease from merchant generation operations due to a decrease at certain nuclear generation facilities ($60 million) primarily due to lower realized prices, as well as the expiration of certain requirements-based power sales contracts in December 2009 ($13 million); and

• A $69 million decrease reflecting the sale of Dominion’s Appalachian E&P business in April 2010.

Other operations and maintenance increased 11%, primarily reflecting:

• A $20 million increase in certain electric transmission-related expenditures;

• A $13 million impairment charge related to electric utility SO₂ emission allowances;

• A $13 million increase in storm damage and service restoration costs; and

• An $8 million increase in outage costs due to an increase in scheduled outage days at certain utility generation facilities partially offset by a decrease in scheduled outage days at certain merchant generation facilities.

Other taxes increased 10% primarily due to additional property tax from increased investments and higher rates, as well as an increase in gross receipts tax due to new non-regulated retail energy customers.

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Other income decreased $65 million primarily due to lower net realized gains (including investment income) on nuclear decommissioning trust funds.

Loss from discontinued operations for the third quarter of 2009 reflects the net impact of Peoples’ interim income tax provision and loss from operations.

Year-to-Date 2010 vs. 2009

Net revenue decreased 1%, primarily reflecting:

• A $343 million decrease from merchant generation operations, primarily due to:

• A decrease at certain nuclear generation facilities ($258 million) largely reflecting a decrease in realized prices;

• The expiration of certain requirements-based power sales contracts in 2009 ($43 million); and

• A decrease at certain fossil generation facilities ($35 million) largely due to an increase in fuel prices; and

• A $151 million decrease reflecting the sale of Dominion’s Appalachian E&P operations ($130 million) and the expiration of fixed-term overriding royalty interests associated with Dominion’s former VPP agreements ($21 million).

These decreases were partially offset by:

• A $369 million increase from electric utility operations, primarily due to an increase in sales to retail customers due to an increase in cooling degree days ($209 million), the impact of Riders C1 and C2, R, S and T ($196 million), and an increase in ancillary services revenue ($57 million) primarily reflecting higher regulation and operating reserves revenue received from PJM, partially offset by a $68 million decrease primarily due to the impact of unfavorable economic conditions on customer usage and other factors;

• A $39 million increase reflecting a benefit resulting from the discontinuance of hedge accounting for certain gas derivatives related to the sale of Appalachian E&P; and

• A $33 million increase related to gas transmission operations largely due to the completion of a Cove Point expansion project.

Other operations and maintenance increased 3% primarily reflecting:

• A $288 million increase in salaries, wages and benefits primarily related to a workforce reduction program;

• A $163 million impairment charge related to State Line; and

• A $103 million increase due to the absence of a benefit in 2009 from a downward revision in the nuclear decommissioning ARO for a unit that is no longer in service.

These increases were partially offset by:

• A $434 million decrease in ceiling test impairment charges related to the carrying value of Dominion’s E&P properties;

• A $27 million decrease in outage costs primarily due to fewer scheduled outage days at certain utility generation facilities; and

• A $23 million decrease due to the sale of Dominion’s Appalachian E&P operations in April 2010.

Other taxes increased 11% primarily due to higher payroll taxes associated with a workforce reduction program ($16 million), additional property tax from increased investments and higher rates ($14 million) and an increase in gross receipts tax due to new non-regulated retail energy customers ($10 million).

Gain on sale of Appalachian E&P operations reflects a gain on the sale of these operations, as described in Note 3 to the Consolidated Financial Statements in this report.

Other income decreased 20%, primarily reflecting an increase in charitable contributions ($48 million) partially offset by the absence of an impairment loss on an equity method investment ($23 million).

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Interest and related charges decreased 9%, primarily due to a benefit resulting from the net effect of the discontinuance of hedge accounting for certain interest rate hedges and subsequent changes in fair value of these interest rate derivatives ($73 million), partially offset by an increase in interest expense associated with a June 2009 junior subordinated note issuance ($26 million).

Income tax expense increased $1.0 billion, primarily reflecting higher federal and state taxes largely due to the gain on the sale of Dominion’s Appalachian E&P business.

Loss from discontinued operations reflects a loss on the sale of Peoples.

Segment Results of Operations

Segment results include the impact of intersegment revenues and expenses, which may result in intersegment profit and loss. Presented below is a summary of contributions by Dominion’s operating segments to net income attributable to Dominion:

	Net Income attributable to Dominion									Diluted EPS
Third Quarter	2010			2009			$ Change			2010			2009			$ Change
(millions, except EPS)
DVP	$	107		$	95		$	12		$	0.18		$	0.16		$	0.02
Dominion Generation		487			459			28			0.83			0.77			0.06
Dominion Energy		92			93			(1	)		0.16			0.16			—
Primary operating segments		686			647			39			1.17			1.09			0.08
Corporate and Other		(111	)		(53	)		(58	)		(0.19	)		(0.09	)		(0.10	)
Consolidated	$	575		$	594		$	(19	)	$	0.98		$	1.00		$	(0.02	)
Year-To-Date
DVP	$	333		$	292		$	41		$	0.56		$	0.49		$	0.07
Dominion Generation		1,088			1,098			(10	)		1.84			1.86			(0.02	)
Dominion Energy		353			372			(19	)		0.59			0.63			(0.04	)
Primary operating segments		1,774			1,762			12			2.99			2.98			0.01
Corporate and Other		736			(466	)		1,202			1.24			(0.79	)		2.03
Consolidated	$	2,510		$	1,296		$	1,214		$	4.23		$	2.19		$	2.04

DVP

Presented below are selected operating statistics related to DVP’s operations:

	Third Quarter							Year-To-Date
	2010		2009		% Change			2010		2009		% Change
Electricity delivered (million MWh)		23.5		21.8		8	%		64.8		62.1		4	%
Degree days (electric distribution service area):
Cooling(1)		1,317		988		33			2,041		1,451		41
Heating(2)		—		5		(100	)		2,323		2,462		(6	)
Average electric distribution customer accounts (thousands)(3)		2,424		2,403		1			2,420		2,401		1
Average retail energy marketing customer accounts (thousands)(3)		2,072		1,747		19			2,019		1,699		19

(1) Cooling degree days are units measuring the extent to which the average daily temperature is greater than 65 degrees Fahrenheit, and are calculated as the difference between 65 degrees and the average temperature for that day.

(2) Heating degree days are units measuring the extent to which the average daily temperature is less than 65 degrees Fahrenheit, and are calculated as the difference between 65 degrees and the average temperature for that day.

(3) Period average.

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Presented below, on an after-tax basis, are the key factors impacting DVP’s net income contribution:

	Third Quarter						Year-To-Date
	2010 vs. 2009						2010 vs. 2009
	Increase (Decrease)						Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	23		$	0.05		$	40		$	0.07
FERC transmission revenue		10			0.02			29			0.06
Other		(1	)		—			(5	)		(0.01	)
Interest expense		2			—			5			0.01
Storm damage and service restoration – electric distribution operations		(8	)		(0.02	)		(15	)		(0.03	)
Retail energy marketing operations		(4	)		(0.01	)		(8	)		(0.02	)
Other		(10	)		(0.02	)		(5	)		(0.01	)
Change in net income contribution	$	12		$	0.02		$	41		$	0.07

Dominion Generation

Presented below are selected operating statistics related to Dominion Generation’s operations:

	Third Quarter							Year-To-Date
	2010		2009		% Change			2010		2009		% Change
Electricity supplied (million MWh):
Utility		23.5		21.8		8	%		64.8		62.1		4	%
Merchant		12.7		12.4		2			35.6		37.1		(4	)
Degree days (electric utility service area):
Cooling		1,317		988		33			2,041		1,451		41
Heating		—		5		(100	)		2,323		2,462		(6	)

Presented below, on an after-tax basis, are the key factors impacting Dominion Generation’s net income contribution:

	Third Quarter						Year-To-Date
	2010 vs. 2009						2010 vs. 2009
	Increase (Decrease)						Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	55		$	0.09		$	89		$	0.15
Rate adjustment clause revenue		27			0.05			73			0.12
Other(1)		(18	)		(0.03	)		(26	)		(0.05	)
PJM ancillary service revenue		15			0.03			28			0.05
Interest expense		5			0.01			13			0.02
Energy supply margin(2)		—			—			(12	)		(0.02	)
Merchant generation margin		(45	)		(0.07	)		(207	)		(0.35	)
Outage costs		(5	)		(0.01	)		17			0.03
Other		(6	)		(0.01	)		15			0.03
Change in net income contribution	$	28		$	0.06		$	(10	)	$	(0.02	)

(1) Primarily reflects the impact of unfavorable economic conditions on customer usage and other factors.

(2) Primarily reflects a reduced benefit from FTRs, due to the crediting of certain FTRs allocated to Virginia Power against Virginia jurisdictional fuel factor expenses subject to deferral accounting beginning July 1, 2009.

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Dominion Energy

Presented below are selected operating statistics related to Dominion Energy’s operations. As discussed in Note 3, in April 2010 Dominion completed the sale of substantially all of its Appalachian E&P operations. As a result, production-related operating statistics for the Dominion Energy segment are no longer significant.

	Third Quarter							Year-To-Date
	2010		2009		% Change			2010		2009		% Change
Gas distribution throughput (bcf):
Sales		2		2		—	%		20		33		(39	)%
Transportation		32		24		33			168		142		18
Heating degree days (gas distribution service area)		78		79		(1	)		3,461		3,828		(10	)
Average gas distribution customer accounts (thousands)(1):
Sales		256		256		—			258		336		(23	)
Transportation		1,029		1,036		(1	)		1,043		973		7

(1) Period average.

Presented below, on an after-tax basis, are the key factors impacting Dominion Energy’s net income contribution:

	Third Quarter 2010 vs. 2009 Increase (Decrease)						Year-To-Date 2010 vs. 2009 Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
E&P disposed operations	$	(20	)	$	(0.03	)	$	(29	)	$	(0.06	)
Producer services(1)		13			0.02			(15	)		(0.03	)
Gas distribution margin:
Weather		—			—			(3	)		(0.01	)
AMR and PIR revenue(2)		3			0.01			8			0.02
Rate changes(3)		6			0.01			8			0.02
Other		1			—			5			0.01
Expired E&P VPP royalty interests		—			—			(12	)		(0.02	)
Cove Point expansion revenue		—			—			20			0.03
Other		(4	)		(0.01	)		(1	)		—
Change in net income contribution	$	(1	)	$	—		$	(19	)	$	(0.04	)

(1) For the quarter, increase largely due to favorable price changes related to economic hedging positions, partially offset by lower physical margins, all associated with natural gas aggregation, marketing, and trading activities. For the year-to-date period, decrease largely due to less favorable price changes related to economic hedging positions and lower physical margins, all associated with natural gas aggregation, marketing, and trading activities.

(2) Primarily reflects an allowed return on investment through the AMR and PIR programs.

(3) Primarily reflects the impact of changes in base rates at East Ohio and Hope.

PAGE 54

Corporate and Other

Presented below are the Corporate and Other segment’s after-tax results:

	Third Quarter									Year-To-Date
	2010			2009			$ Change			2010			2009			$ Change
(millions, except EPS)
Specific items attributable to operating segments	$	(4	)	$	35		$	(39	)	$	1,061		$	(239	)	$	1,300
Specific items attributable to corporate operations:
Peoples discontinued operations		—			(41	)		41			(147	)		(47	)		(100	)
Other		(24	)		10			(34	)		(9	)		14			(23	)
Total specific items		(28	)		4			(32	)		905			(272	)		1,177
Other corporate operations		(83	)		(57	)		(26	)		(169	)		(194	)		25
Total net benefit (expense)	$	(111	)	$	(53	)	$	(58	)	$	736		$	(466	)	$	1,202
EPS impact	$	(0.19	)	$	(0.09	)	$	(0.10	)	$	1.24		$	(0.79	)	$	2.03

Total Specific Items

Corporate and Other includes specific items that are not included in profit measures evaluated by management in assessing segment performance or in allocating resources among the segments. See Note 19 to the Consolidated Financial Statements for discussion of these items.

Other Corporate Operations

Third Quarter 2010 vs. 2009

Net expenses increased $26 million primarily reflecting higher net interest expense.

Year-to-Date 2010 vs. 2009

Net expenses decreased $25 million primarily due to a $41 million net benefit resulting from the discontinuance of hedge accounting and subsequent changes in fair value of certain interest rate derivatives and a $15 million increase in consolidated tax benefits that are not attributed to the operating segments, partially offset by higher interest expense ($32 million).

Virginia Power

Results of Operations

Presented below is a summary of Virginia Power’s consolidated results:

	Third Quarter						Year-To-Date
	2010		2009		$ Change		2010		2009		$ Change
(millions)
Net income	$	380	$	315	$	65	$	742	$	668	$	74

Overview

Third Quarter 2010 vs. 2009

Net income increased 21%, primarily reflecting the impact of favorable weather.

Year-To-Date 2010 vs. 2009

Net income increased 11%, primarily reflecting the combined effects of favorable weather and a benefit from rate adjustment clauses, partially offset by charges related to a workforce reduction program.

PAGE 55

Analysis of Consolidated Operations

Presented below are selected amounts related to Virginia Power’s results of operations:

	Third Quarter							Year-To-Date
	2010		2009		$ Change			2010		2009		$ Change
(millions)
Operating revenue	$	2,111	$	1,938	$	173		$	5,561	$	5,472	$	89
Electric fuel and other energy-related purchases		694		740		(46	)		1,915		2,219		(304	)
Purchased electric capacity		116		95		21			331		307		24
Net revenue		1,301		1,103		198			3,315		2,946		369
Other operations and maintenance		404		339		65			1,240		1,067		173
Depreciation and amortization		171		162		9			499		479		20
Other taxes		53		48		5			170		145		25
Other income		25		33		(8	)		67		65		2
Interest and related charges		88		89		(1	)		259		263		(4	)
Income tax expense		230		183		47			472		389		83

An analysis of Virginia Power’s results of operations follows:

Third Quarter 2010 vs. 2009

Net revenue increased 18%, primarily reflecting:

• A $127 million increase in sales to retail customers due to an increase in cooling degree days;

• The impact from Riders C1 and C2, R, S and T ($79 million); and

• An increase in ancillary services revenue ($31 million) primarily reflecting higher regulation and operating reserves revenue received from PJM.

These increases were partially offset by:

• A $39 million decrease due to the impact of unfavorable economic conditions on customer usage and other factors.

Other operations and maintenance increased 19%, primarily reflecting:

• A $20 million increase in certain transmission-related expenditures;

• Higher outage costs largely reflecting more scheduled outage days at certain nuclear generating facilities ($19 million);

• Higher storm damage and service restoration costs ($13 million); and

• A $13 million impairment charge related to SO₂ emission allowances.

Income tax expense increased 26%, primarily reflecting higher pre-tax income in 2010.

Year-to-Date 2010 vs. 2009

Net revenue increased 13%, primarily reflecting:

• An increase in sales to retail customers due to an increase in cooling degree days ($209 million);

• The impact of Riders C1 and C2, R, S and T ($196 million); and

• An increase in ancillary services revenue ($57 million) primarily reflecting higher regulation and operating reserves revenue received from PJM.

These increases were partially offset by:

• A $68 million decrease due to the impact of unfavorable economic conditions on customer usage and other factors.

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Other operations and maintenance increased 16%, primarily reflecting:

• An increase in salaries, wages and benefits primarily due to a workforce reduction program ($173 million);

• An increase in certain electric transmission-related expenditures ($29 million); and

• Higher storm damage and service restoration costs ($24 million).

These increases were partially offset by:

• A decrease in outage costs primarily due to fewer scheduled outage days at certain fossil generation facilities ($38 million); and

• A decrease in bad debt expense ($18 million).

Other taxes increased 17% primarily reflecting additional property tax due to increased investments and higher rates ($10 million), higher payroll taxes associated with a workforce reduction program ($7 million) and incremental use tax that is recoverable through a customer surcharge ($5 million).

Income tax expense increased 21%, primarily reflecting higher pretax income ($61 million) and a charge related to 2010 health care law changes that eliminated tax deductions for a portion of certain retiree health care costs ($16 million).

Segment Results of Operations

Presented below is a summary of contributions by Virginia Power’s operating segments to net income:

	Third Quarter									Year-To-Date
	2010			2009			$ Change			2010			2009			$ Change
(millions)
DVP	$	102		$	83		$	19		$	300		$	249		$	51
Dominion Generation		286			233			53			589			426			163
Primary operating segments		388			316			72			889			675			214
Corporate and Other		(8	)		(1	)		(7	)		(147	)		(7	)		(140	)
Consolidated	$	380		$	315		$	65		$	742		$	668		$	74

DVP

Presented below are operating statistics related to Virginia Power’s DVP segment:

	Third Quarter							Year-To-Date
	2010		2009		% Change			2010		2009		% Change
Electricity delivered (million MWh)		23.5		21.8		8	%		64.8		62.1		4	%
Degree days (electric distribution service area):
Cooling		1,317		988		33			2,041		1,451		41
Heating		—		5		(100	)		2,323		2,462		(6	)
Average electric distribution customer accounts (thousands)(1)		2,424		2,403		1			2,420		2,401		1

(1) Period average.

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Presented below, on an after-tax basis, are the key factors impacting Virginia Power’s DVP segment’s net income contribution:

	Third Quarter			Year-to-Date
	2010 vs. 2009			2010 vs. 2009
	Increase (Decrease)			Increase (Decrease)
(millions)
Regulated electric sales:
Weather	$	23		$	40
FERC transmission revenue		10			29
Other		(1	)		(5	)
Interest expense		2			5
Storm damage and service restoration – electric distribution operations		(8	)		(15	)
Other		(7	)		(3	)
Change in net income contribution	$	19		$	51

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Dominion Generation

Presented below are operating statistics related to Virginia Power’s Dominion Generation segment:

	Third Quarter							Year-To-Date
	2010		2009		% Change			2010		2009		% Change
Electricity supplied (million MWh):		23.5		21.8		8	%		64.8		62.1		4	%
Degree days (electric utility service area):
Cooling		1,317		988		33			2,041		1,451		41
Heating		—		5		(100	)		2,323		2,462		(6	)

Presented below, on an after-tax basis, are the key factors impacting Virginia Power’s Dominion Generation segment’s net income contribution:

	Third Quarter			Year-To-Date
	2010 vs. 2009			2010 vs. 2009
	Increase (Decrease)			Increase (Decrease)
(millions)
Regulated electric sales:
Weather	$	55		$	89
Rate adjustment clause revenue		27			73
Other(1)		(18	)		(26	)
PJM ancillary service revenue		15			28
Outage costs		(12	)		24
Energy supply margin(2)		—			(12	)
Other		(14	)		(13	)
Change in net income contribution	$	53		$	163

(1) Primarily reflects the impact of unfavorable economic conditions on customer usage and other factors.

(2) Primarily reflects a reduced benefit from FTRs, due to the crediting of certain FTRs allocated to Virginia Power against Virginia jurisdictional fuel factor expenses subject to deferral accounting beginning July 1, 2009.

Corporate and Other

Corporate and Other includes specific items that are not included in profit measures evaluated by management in assessing segment performance or in allocating resources among the segments. See Note 19 to the Consolidated Financial Statements for discussion of these items.

Liquidity and Capital Resources

Dominion and Virginia Power 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 cash provided by operations are generally satisfied with proceeds from short-term borrowings. Long-term cash needs are met through issuances of debt and/or equity securities. Net proceeds from the sale of Dominion’s Appalachian E&P operations have been or will be used to offset all of Dominion’s equity needs for 2010 and its market equity issuances for 2011, repurchase common stock, fund contributions to Dominion’s pension plans and the Dominion Foundation, reduce debt and offset the majority of the impact of Virginia Power’s rate case settlement.

At September 30, 2010, Dominion had $3.4 billion of unused capacity under its credit facilities, including $1.1 billion of unused capacity under joint credit facilities available to Virginia Power.

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A summary of Dominion’s cash flows is presented below:

	2010			2009
(millions)
Cash and cash equivalents at January 1(1)	$	50		$	71
Cash flows provided by (used in):
Operating activities		1,884			2,982
Investing activities		1,225			(2,744	)
Financing activities		(2,713	)		(256	)
Net increase (decrease) in cash and cash equivalents		396			(18	)
Cash and cash equivalents at September 30(2)	$	446		$	53

(1) 2010 and 2009 amounts include $2 million and $5 million, respectively, of cash classified as held for sale in Dominion’s Consolidated Balance Sheets.

(2) 2009 amount includes $3 million of cash classified as held for sale in Dominion’s Consolidated Balance Sheet.

A summary of Virginia Power’s cash flows is presented below:

	2010			2009
(millions)
Cash and cash equivalents at January 1	$	19		$	27
Cash flows provided by (used in):
Operating activities		1,238			1,586
Investing activities		(1,708	)		(1,905	)
Financing activities		473			315
Net increase (decrease) in cash and cash equivalents		3			(4	)
Cash and cash equivalents at September 30	$	22		$	23

Operating Cash Flows

Net cash provided by Dominion’s operating activities decreased by $1.1 billion, primarily due to lower deferred fuel and gas cost recoveries, a contribution to Dominion’s pension plans, lower merchant generation margins and refunds related to the Virginia rate case settlement, partially offset by lower income tax payments, lower margin collateral requirements and the favorable impact of weather and rate adjustment clauses on electric utility operations.

Net cash provided by Virginia Power’s operating activities decreased by $348 million, primarily due to lower deferred fuel cost recoveries, refunds related to the Virginia rate case settlement, a contribution to the Dominion pension plans and payments related to workforce reduction programs, partially offset by the favorable impact of weather, the impact of rate adjustment clauses and lower income tax payments in 2010.

Dominion believes that its operations provide a stable source of cash flow to contribute to planned levels of capital expenditures and maintain or grow the dividend on common shares. Virginia Power believes that its operations provide a stable source of cash flow to contribute to planned levels of capital expenditures and provide dividends to Dominion.

The Companies’ operations are subject to risks and uncertainties that may negatively impact the timing or amounts of operating cash flows, which are discussed in Item 1A. Risk Factors in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009.

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Credit Risk

Dominion’s exposure to potential concentrations of credit risk results primarily from its energy marketing and price risk management activities. Presented below is a summary of Dominion’s credit exposure as of September 30, 2010 for these activities. Gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights.

	Gross  Credit Exposure		Credit Collateral		Net Credit Exposure
(millions)
Investment grade(1)	$	516	$	70	$	446
Non-investment grade(2)		21		10		11
No external ratings:
Internally rated—investment grade(3)		134		—		134
Internally rated—non-investment grade(4)		85		—		85
Total	$	756	$	80	$	676

(1) Designations as investment grade are based upon minimum credit ratings assigned by Moody’s and Standard & Poor’s. The five largest counterparty exposures, combined, for this category represented approximately 34% of the total net credit exposure.

(2) The five largest counterparty exposures, combined, for this category represented approximately 1% of the total net credit exposure.

(3) The five largest counterparty exposures, combined, for this category represented approximately 16% of the total net credit exposure.

(4) The five largest counterparty exposures, combined, for this category represented approximately 8% of the total net credit exposure.

Virginia Power’s exposure to potential concentrations of credit risk results primarily from sales to wholesale customers. Presented below is a summary of Virginia Power’s gross credit exposure as of September 30, 2010 for these activities. Gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights.

	Gross  Credit Exposure		Credit Collateral		Net Credit Exposure
(millions)
Investment grade(1)	$	3	$	2	$	1
Non-investment grade(2)		13		10		3
No external ratings:
Internally rated—non-investment grade(3)		2		—		2
Total	$	18	$	12	$	6

(1) Designations as investment grade are based on minimum credit ratings assigned by Moody’s and Standard & Poor’s. The three counterparty exposures, combined, for this category represented approximately 27% of the total net credit exposure.

(2) The only counterparty exposure for this category represented 43% of the total net credit exposure.

(3) The only counterparty exposure for this category represented 30% of the total net credit exposure.

Investing Cash Flows

For the nine months ended September 30, 2010, net cash provided by Dominion’s investing activities was $1.2 billion as compared to net cash used in investing activities of $2.7 billion in 2009, primarily reflecting the proceeds received from the sale of Dominion’s Appalachian E&P operations in April 2010 and the sale of Peoples in February 2010. A portion of the proceeds was invested in time deposit certificates and other short-term securities.

Net cash used in Virginia Power’s investing activities decreased by $197 million, primarily due to lower capital expenditures.

Financing Cash Flows and Liquidity

Dominion and Virginia Power rely on capital markets as significant sources of funding for capital requirements not satisfied by cash provided by their operations. As discussed further in Credit Ratings and Debt Covenants in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, the Companies’ ability to borrow funds or issue securities and the return demanded by investors are affected by credit ratings. In addition, the raising of external capital is subject to certain regulatory requirements, including registration with the SEC and, in the case of Virginia Power, approval by the Virginia Commission.

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Each of the Companies meets the definition of a well-known seasoned issuer under SEC rules governing the registration, communications and offering processes under the Securities Act of 1933. The rules provide for a streamlined shelf registration process to provide registrants with timely access to capital. This allows the Companies to use automatic shelf registration statements to register any offering of securities, other than those for business combination transactions.

Net cash used in Dominion’s financing activities increased by $2.5 billion, primarily due to net debt repayments in 2010 as compared to net debt issuances in 2009, and net repurchases of common stock in 2010 as compared to issuances of common stock in 2009. This reflects the use of proceeds from the sale of Dominion’s Appalachian E&P operations and Peoples.

Net cash provided by Virginia Power’s financing activities increased by $158 million, primarily due to higher net debt issuances in 2010 as compared to 2009, as a result of lower cash flow from operations.

See Note 14 to the Consolidated Financial Statements for further information regarding Dominion’s and Virginia Power’s credit facilities, liquidity and significant financing transactions, including stock repurchases.

Credit Ratings

Credit ratings are intended to provide banks and capital market participants with a framework for comparing the credit quality of securities and are not a recommendation to buy, sell or hold securities. In the Credit Ratings section of MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, there is a discussion on the use of capital markets by the Companies, as well as the impact of credit ratings on the accessibility and costs of using these markets. As of September 30, 2010, there have been no changes in the Companies’ credit ratings.

Debt Covenants

In the Debt Covenants section of MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, there is a discussion on the various covenants present in the enabling agreements underlying the Companies’ debt. As of September 30, 2010, there have been no material changes to debt covenants, nor any events of default under the Companies’ debt covenants.

Future Cash Payments for Contractual Obligations and Planned Capital Expenditures

As of September 30, 2010, there have been no material changes outside the ordinary course of business to Dominion’s or Virginia Power’s contractual obligations as disclosed in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2009.

As of September 30, 2010, Dominion’s planned capital expenditures for 2011 and 2012 are expected to total approximately $4.0 billion and $5.1 billion, respectively. The increases from the expected amounts previously disclosed in Dominion’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010, primarily reflect additional planned spending to expand DTI’s gas transmission pipeline network in the Marcellus Shale region and support the development of Virginia Power’s power station project in Warren County, Virginia, as well as an initial estimate of spending to comply with certain expected environmental regulations. There have been no material changes to Dominion’s planned capital expenditures for 2010 as compared to the expected amounts disclosed in Dominion’s Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010.

Virginia Power’s planned capital expenditures for 2012 are expected to total approximately $3.4 billion. The increase from the expected amount previously disclosed in Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, primarily reflects additional planned spending to support the development of its power station project in Warren County, Virginia, as well as an initial estimate of spending to comply with certain expected environmental regulations. There have been no material changes to Virginia Power’s planned capital expenditures for 2010 or 2011 as compared to the expected amounts disclosed in Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009.

Use of Off-Balance Sheet Arrangements

Other than a $130 million reduction in guarantees issued to third parties and equity method investees, as of September 30, 2010, there have been no material changes in the off-balance sheet arrangements disclosed in MD&A in Dominion’s Annual Reports on Form 10-K for the year ended December 31, 2009.

Future Issues and Other Matters

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 dates of Dominion’s and Virginia Power’s Consolidated Financial Statements that may impact the Companies’ future results of operations and/or financial condition. This section should be read in conjunction with Item 1. Business and Future Issues and Other Matters in MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009 and Future Issues and Other Matters in their Quarterly Report on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010.

Regulatory Matters

See Note 14 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, Note 12 to the Consolidated Financial Statements in their Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010 and Note 12 to the Consolidated Financial Statements in this report for additional information on various regulatory matters.

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Environmental Matters

Dominion and Virginia Power are subject to costs resulting from a number of federal, state and local laws and regulations designed to protect human health and the environment. These laws and regulations affect future planning and existing operations. They can result in increased capital, operating and other costs as a result of compliance, remediation, containment and monitoring obligations. See Note 23 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, Note 15 to the Consolidated Financial Statements in their Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010 and Note 15 to the Consolidated Financial Statements in this report for additional information on various environmental matters.

Legal Matters

See Item 3. Legal Proceedings in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009 and Part II, Item 1. Legal Proceedings in their Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010 and this report for additional information on various legal matters.

Warren County Project

In March 2008, Virginia Power purchased a power station development project in Warren County, Virginia, which it intends to develop as a combined-cycle, natural gas-fired power station. Subject to the receipt of regulatory approvals, the project is expected to generate up to 1,300 MW of electricity. If the project is approved, construction would begin in 2012, with commercial operations expected to commence in 2014.

DTI – TGP Firm Transportation Agreement

In August 2010, DTI entered into a 10-year lease agreement with TGP for firm capacity to move Marcellus shale natural gas supplies from TGP’s 300 Line pipeline system in northern Pennsylvania to its 200 Line pipeline system in upstate New York. The $46 million project, known as the Ellisburg-to-Craigs Project, is expected to have capacity of approximately 150,000 dekatherms per day. Subject to the receipt of regulatory approvals, the project will involve the construction by DTI of additional compression facilities and a new measurement and regulating station at the Craigs interconnect with TGP in New York. DTI would also add regulating facilities on its system in northern Pennsylvania. DTI plans to file a certificate application with FERC in the fourth quarter of 2010. If the Ellisburg-to-Craigs Project is approved, construction will begin in March 2012, with a planned in-service date of November 1, 2012.

NERC Facility Ratings Methodology Alert

NERC is the FERC-approved Electric Reliability Organization charged with overseeing the reliability of the bulk electric system in the U.S. In connection with its reliability mandate, NERC established the facility ratings methodology, which is intended to ensure that facility ratings used in the reliable planning and operation of the bulk electric system are determined based on an established methodology. In October 2010, NERC issued an industry alert identifying possible discrepancies between the design and actual field conditions of transmission facilities as a potential reliability issue. The alert recommends that entities review their current facilities rating methodology to verify that the methodology is based on actual field conditions, rather than solely on design documents, and to take corrective action if necessary. Dominion and Virginia Power are evaluating their transmission facilities for any discrepancies between design and actual field conditions. Until such evaluation is complete, it is not possible to determine the impact of the alert to Dominion or Virginia Power.

Dodd-Frank Act

The Dodd-Frank Act was enacted into law in July 2010 in an effort to improve regulation of financial markets. The Dodd-Frank Act includes provisions that will require certain over-the-counter derivatives, or swaps, to be centrally cleared and executed through an exchange or other approved trading platform. Swaps by non-financial entities that use swaps to hedge or mitigate commercial risk, often referred to as “end users,” can be exempted from these clearing and exchange trading requirements. In addition, the Dodd-Frank Act allows the CFTC to impose capital and initial and variation margin requirements on entities who execute swaps. End users were not expressly exempt from these requirements for non-cleared swaps; however, key legislators indicated in a public letter that it was their intention to exclude commercial hedging transactions by end users from these requirements. Final rules for the over-the-counter derivatives-related provisions of the Dodd-Frank Act, including the clearing, exchange trading and capital and margin requirements, will be established through the CFTC’s rulemaking process, which must be completed by July 2011. If, as a result of the rulemaking process, Dominion’s or Virginia Power’s derivative activities are not exempted from the clearing, exchange trading and capital and margin requirements, the Companies could be subject to higher costs for their derivative activities, including from higher margin requirements. In addition, implementation of, and compliance with, the over-the-counter derivatives provisions of the Dodd-Frank Act by the Companies’ swap counterparties could result in increased costs related to the Companies’ derivative activities. Due to the ongoing rulemaking process, the Companies are currently unable to assess the potential impact of the Dodd-Frank Act’s derivatives-related provisions on their financial condition, results of operations or cash flows.

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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. MD&A of this Form 10-Q. The reader’s attention is directed to those paragraphs for discussion of various risks and uncertainties that may impact Dominion and Virginia Power.

Market Risk Sensitive Instruments and Risk Management

Dominion’s and Virginia Power’s financial instruments, commodity contracts and related financial derivative instruments are exposed to potential losses due to adverse changes in commodity prices, interest rates and equity security prices as described below. Commodity price risk is present in Dominion’s and Virginia Power’s electric operations, Dominion’s gas production and procurement operations, and Dominion’s energy marketing and trading operations due to the exposure to market shifts in prices received and paid for electricity, natural gas and other commodities. The Companies use commodity derivative contracts to manage price risk exposures for these operations. Interest rate risk is generally related to their outstanding debt. In addition, they are exposed to investment price risk through various portfolios of equity and debt securities.

The following 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% unfavorable change in commodity prices and interest rates.

Commodity Price Risk

To manage price risk, Dominion and Virginia Power primarily hold commodity-based financial derivative instruments held for non-trading purposes associated with purchases and sales of electricity, natural gas and other energy-related products. As part of its strategy to market energy and to manage related risks, Dominion also holds commodity-based financial derivative instruments for trading purposes.

The derivatives used to manage commodity price risk are executed within established policies and procedures and may include instruments such as futures, forwards, swaps, options and FTRs that are sensitive to changes in the related commodity prices. For sensitivity analysis purposes, the hypothetical change in market prices of commodity-based financial derivative 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. Prices and volatility are principally determined based on observable market prices.

A hypothetical 10% unfavorable change in market prices of Dominion’s non-trading commodity-based financial derivative instruments would have resulted in a decrease in fair value of approximately $152 million and $150 million as of September 30, 2010 and December 31, 2009, respectively. A hypothetical 10% unfavorable change in commodity prices would have resulted in a decrease of approximately $11 million in the fair value of Dominion’s commodity-based financial derivative instruments held for trading purposes as of both September 30, 2010 and December 31, 2009.

A hypothetical 10% unfavorable change in commodity prices would have resulted in a decrease of approximately $2 million and $3 million in the fair value of Virginia Power’s non-trading commodity-based financial derivatives as of September 30, 2010 and December 31, 2009, respectively.

The impact of a change in energy commodity prices on Dominion’s and Virginia Power’s non-trading commodity-based financial derivative 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 commodity derivative instruments used for hedging purposes, to the extent realized, will generally be offset by recognition of the hedged transaction, such as revenue from physical sales of the commodity.

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Interest Rate Risk

Dominion and Virginia Power may use forward-starting interest rate swaps and interest rate lock agreements as anticipatory hedges. At December 31, 2009, Dominion and Virginia Power had $1.7 billion and $850 million, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. At December 31, 2009, a hypothetical 10% decrease in market interest rates would have resulted in a decrease of approximately $62 million and $33 million in the fair value of these interest rate derivatives held by Dominion and Virginia Power, respectively. Subsequent to June 30, 2010, all forward-starting interest rate swap contracts were terminated; therefore, Dominion and Virginia Power have no sensitivity to changes in interest rates related to these interest rate swaps.

Investment Price Risk

Dominion and Virginia Power are subject to investment price risk due to securities held as investments in decommissioning and rabbi trust funds that are managed by third-party investment managers. These trust funds primarily hold marketable securities that are reported in the Consolidated Balance Sheets at fair value.

Dominion recognized net realized gains (including investment income) on nuclear decommissioning and rabbi trust investments of $63 million, $6 million and $25 million for the nine months ended September 30, 2010 and 2009 and for the year ended December 31, 2009, respectively. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. For the nine months ended September 30, 2010 and 2009 and the year ended December 31, 2009, Dominion recorded, in AOCI and regulatory liabilities, a net increase in unrealized gains on these investments of $55 million, $308 million and $360 million, respectively.

Virginia Power recognized net realized gains (including investment income) on nuclear decommissioning trust investments of $29 million for the nine months ended September 30, 2010. Virginia Power recognized net realized losses (net of investment income) on nuclear decommissioning trust investments of $7 million and $3 million for the nine months ended September 30, 2009 and for the year ended December 31, 2009, respectively. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Virginia Power recorded, in AOCI and regulatory liabilities, a net increase in unrealized gains on these investments of $21 million, $130 million and $149 million for the nine months ended September 30, 2010 and 2009 and for the year ended December 31, 2009, respectively.

Dominion sponsors employee pension and other postretirement benefit plans, in which Dominion’s and Virginia Power’s employees participate, that hold investments in trusts to fund benefit payments. If the values of investments held in these trusts decline, it will result in future increases in the periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of contributions to be made to the employee benefit plans.

ITEM 4. CONTROLS AND PROCEDURES

Senior management of each of Dominion and Virginia Power, including Dominion’s and Virginia Power’s CEO and CFO, evaluated the effectiveness of each of their respective Companies’ disclosure controls and procedures as of the end of the period covered by this report. Based on this evaluation process, both Dominion’s and Virginia Power’s CEO and CFO have concluded that each of the Companies’ disclosure controls and procedures are effective.

There were no changes in either Dominion’s or Virginia Power’s internal control over financial reporting that occurred during the last fiscal quarter that have materially affected, or are reasonably likely to materially affect, either of the Companies’ internal control over financial reporting.

The Dodd-Frank Act permanently exempts small public companies with less than $75 million in market capitalization (non-accelerated filers) from the requirement to obtain an external audit on the effectiveness of internal financial reporting controls provided in Section 404(b) of the Sarbanes-Oxley Act. Virginia Power, as a subsidiary of Dominion, does not have publicly traded common stock. As a result, Virginia Power is permanently exempt from providing an attestation report on internal controls over financial reporting by an independent registered public accounting firm. Disclosure of management attestations on internal controls over financial reporting under existing Section 404(a) is still required.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, Dominion and Virginia Power 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 the Companies, or permits issued by various local, state and/or federal agencies for the construction or operation of facilities. Administrative proceedings may also be pending on these matters. In addition, in the ordinary course of business, the Companies and their subsidiaries are involved in various legal proceedings. Dominion and Virginia Power believe that the ultimate resolution of these proceedings will not have a material adverse effect on their financial position, liquidity or results of operations. See Notes 12 and 15 to the Consolidated Financial Statements and Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009 and their Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010 for discussions on various environmental and other regulatory proceedings to which Dominion and/or Virginia Power are a party.

ITEM 1A. RISK FACTORS

Dominion’s and Virginia Power’s businesses are influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond the Companies’ control. A number of these risk factors have been identified in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009, which should be taken into consideration when reviewing the information contained in this report. There have been no material changes with regard to the risk factors previously disclosed in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2009 or their Quarterly Reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010. For other factors that may cause actual results to differ materially from those indicated in any forward-looking statement or projection contained in this report, see Forward-Looking Statements in MD&A.

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

Dominion

ISSUER PURCHASES OF EQUITY SECURITIES

Period	(a) Total Number of Shares (or Units) Purchased(1)		(b) Average Price Paid per Share (or Unit)(2)		(c) Total Number of  Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs		(d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased under the Plans or Programs(3)
7/1/10-7/31/10		542,769	$	42.53		540,000	41,243,420 shares/ $2.15 billion
8/1/10-8/31/10		8,257,797		43.57		8,256,600	32,986,820 shares/ $1.79 billion
9/1/10-9/30/10		401,087		43.20		400,408	32,586,412 shares/ $1.78 billion
Total		9,201,653	$	43.49		9,197,008	32,586,412 shares/ $1.78 billion

(1) In July, August and September 2010, 2,769 shares, 1,197 shares and 679 shares, respectively, were tendered by employees to satisfy tax withholding obligations on vested restricted and goal-based stock.

(2) Represents the weighted-average price paid per share.

(3) The remaining repurchase authorization is pursuant to repurchase authority granted by the Dominion Board of Directors in February 2005, as modified in June 2007. The aggregate authorization granted by the Dominion Board of Directors was 86 million shares (as adjusted to reflect a two-for-one stock split distributed in November 2007) not to exceed $4 billion.

PAGE 67

ITEM 6. EXHIBITS

Exhibit Number	Description	Dominion	Virginia Power
3.1.a	Dominion Resources, Inc. Articles of Incorporation as amended and restated effective May 20, 2010 (Exhibit 3.1, Form 8-K filed May 20, 2010, File No. 1-8489).	X
3.1.b	Virginia Electric and Power Company Restated Articles of Incorporation, as in effect on October 28, 2003 (Exhibit 3.1, Form 10-Q for the quarter ended September 30, 2003 filed November 7, 2003, File No. 1-2255).		X
3.2.a	Dominion Resources, Inc. Bylaws, as amended and restated effective May 18, 2010 (Exhibit 3.2, Form 8-K filed May 20, 2010, File No. 1-8489)	X
3.2.b	Virginia Electric and Power Company Amended and Restated Bylaws, effective June 1, 2009 (Exhibit 3.1, Form 8-K filed June 3, 2009, File No. 1-2255).		X
4	Dominion Resources, Inc. and Virginia Electric and Power Company agree to furnish to the Securities and Exchange Commission upon request any other instrument with respect to long-term debt as to which the total amount of securities authorized does not exceed 10% of either of their total consolidated assets.	X	X

PAGE 68

Exhibit Number	Description	Dominion	Virginia Power
4.1	Form of Senior Indenture, dated June 1, 2000, between Dominion Resources, Inc. and The Bank of New York Mellon (as successor trustee to JP Morgan Chase Bank (formerly The Chase Manhattan Bank)), as Trustee (Exhibit 4(iii), Form S-3 Registration Statement filed December 21, 1999, File No. 333-93187); Form of First Supplemental Indenture, dated June 1, 2000 (Exhibit 4.2, Form 8-K filed June 22, 2000, File No. 1-8489); Forms of Second and Third Supplemental Indentures, dated July 1, 2000 (Exhibits 4.2 and 4.3, Form 8-K filed July 11, 2000, File No. 1-8489); Fourth Supplemental Indenture, dated September 1, 2000 (Exhibit 4.2, Form 8-K filed September 8, 2000, File No. 1-8489); Sixth Supplemental Indenture, dated September 1, 2000 (Exhibit 4.3, Form 8-K filed September 11, 2000, File No. 1-8489); Form of Seventh Supplemental Indenture, dated October 1, 2000 (Exhibit 4.2, Form 8-K filed October 12, 2000, File No. 1-8489); Form of Eighth Supplemental Indenture, dated January 1, 2001 (Exhibit 4.2, Form 8-K filed January 24, 2001, File No. 1-8489); Form of Ninth Supplemental Indenture, dated May 1, 2001 (Exhibit 4.4, Form 8-K filed May 25, 2001, File No. 1-8489); Form of Tenth Supplemental Indenture, dated March 1, 2002 (Exhibit 4.2, Form 8-K filed March 18, 2002, File No. 1-8489); Form of Eleventh Supplemental Indenture, dated June 1, 2002 (Exhibit 4.2, Form 8-K filed June 25, 2002, File No. 1- 8489); Form of Twelfth Supplemental Indenture, dated September 1, 2002 (Exhibit 4.2, Form 8-K filed September 11, 2002, File No. 1-8489); Thirteenth Supplemental Indenture, dated September 16, 2002 (Exhibit 4.1, Form 8-K filed September 17, 2002, File No. 1-8489); Fourteenth Supplemental Indenture, dated August 1, 2003 (Exhibit 4.4, Form 8-K filed August 20, 2003, File No. 1-8489); Forms of Fifteenth and Sixteenth Supplemental Indentures, dated December 1, 2002 (Exhibits 4.2 and 4.3, Form 8-K filed December 13, 2002, File No. 1-8489); Forms of Seventeenth and Eighteenth Supplemental Indentures, dated February 1, 2003 (Exhibits 4.2 and 4.3, Form 8-K filed February 11, 2003, File No. 1-8489; Forms of Twentieth and Twenty-First Supplemental Indentures, dated March 1, 2003 (Exhibits 4.2 and 4.3, Form 8-K filed March 4, 2003, File No. 1-8489); Form of Twenty-Second Supplemental Indenture, dated July 1, 2003 (Exhibit 4.2, Form 8-K filed July 22, 2003, File No. 1-8489); Form of Twenty-Third Supplemental Indenture, dated December 1, 2003 (Exhibit 4.2, Form 8-K filed December 10, 2003, File No. 1-8489); Forms of Twenty-Fifth and Twenty-Sixth Supplemental Indentures, dated January 1, 2004 (Exhibits 4.2 and 4.3, Form 8-K filed January 14, 2004, File No. 1-8489); Form of Twenty-Seventh Supplemental Indenture, dated December 1, 2004 (Exhibit 4.2, Form S-4 Registration Statement filed November 10, 2004, File No. 333-120339); Forms of Twenty-Eighth and Twenty-Ninth Supplemental Indentures, dated June 1, 2005 (Exhibits 4.2 and 4.3, Form 8-K filed June 17, 2005, File No. 1-8489); Form of Thirtieth Supplemental Indenture, dated July 1, 2005 (Exhibit 4.2, Form 8-K filed July 12, 2005, File No. 1-8489); Form of Thirty-First Supplemental Indenture, dated September 1, 2005 (Exhibit 4.2, Form 8-K filed September 26, 2005, File No. 1-8489); Forms of Thirty-Second and Thirty-Third Supplemental Indentures, dated November 1, 2006 (Exhibits 4.2 and 4.3, Form 8-K filed November 13, 2006, File No. 1-8489); Form of Thirty-Fourth Supplemental Indenture, dated November 1, 2007 (Exhibit 4.2, Form 8-K filed November 29, 2007, File No. 1-8489); Forms of Thirty-Fifth, Thirty-Sixth and Thirty-Seventh Supplemental Indentures, dated June 1, 2008 (Exhibits 4.2, 4.3 and 4.4, Form 8-K filed June 16, 2008, File No. 1-8489); Form of Thirty-Eighth Supplemental and Amending Indenture, dated November 1, 2008 (Exhibit 4.2, Form 8-K filed November 26, 2008, File No. 1-8489); Thirty-Ninth Supplemental Indenture Amending the Twenty-Seventh Supplemental Indenture, dated December 1, 2008 and effective as of December 16, 2008 (Exhibit 4.1, Form 8-K filed December 5, 2008, File No. 1-8489); Form of Thirty-Ninth Supplemental Indenture, dated August 1, 2009 (Exhibit 4.3, Form 8-K filed August 12, 2009, File No. 1-8489); Fortieth Supplemental Indenture, dated August 1, 2010 (Exhibit 4.3, Form 8-K filed September 2, 2010, File No. 1-8489).	X

PAGE 69

Exhibit Number	Description	Dominion	Virginia Power
4.2	Form of Senior Indenture, dated June 1, 1998, between Virginia Electric and Power Company and The Bank of New York Mellon (as successor trustee to JP Morgan Chase Bank (formerly The Chase Manhattan Bank)), as Trustee (Exhibit 4(iii), Form S-3 Registration Statement filed February 27, 1998, File No. 333-47119); Form of First Supplemental Indenture, dated June 1, 1998 (Exhibit 4.2, Form 8-K filed June 12, 1998, File No. 1-2255); Form of Second Supplemental Indenture, dated June 1, 1999 (Exhibit 4.2, Form 8-K filed June 4, 1999, File No. 1-2255); Form of Third Supplemental Indenture, dated November 1, 1999 (Exhibit 4.2, Form 8-K filed October 27, 1999, File No. 1-2255); Forms of Fourth and Fifth Supplemental Indentures, dated March 1, 2001 (Exhibits 4.2 and 4.3, Form 8-K filed March 26, 2001, File No. 1-2255); Form of Sixth Supplemental Indenture, dated January 1, 2002 (Exhibit 4.2, Form 8-K filed January 29, 2002, File No. 1-2255); Seventh Supplemental Indenture, dated September 1, 2002 (Exhibit 4.4, Form 8-K filed September 11, 2002, File No. 1-2255); Form of Eighth Supplemental Indenture, dated February 1, 2003 (Exhibit 4.2, Form 8-K filed February 27, 2003, File No. 1-2255); Forms of Ninth and Tenth Supplemental Indentures, dated December 1, 2003 (Exhibits 4.2 and 4.3, Form 8-K filed December 4, 2003, File No. 1-2255); Form of Eleventh Supplemental Indenture, dated December 1, 2003 (Exhibit 4.2, Form 8-K filed December 11, 2003, File No. 1-2255); Forms of Twelfth and Thirteenth Supplemental Indentures, dated January 1, 2006 (Exhibits 4.2 and 4.3, Form 8-K filed January 12, 2006, File No. 1-2255); Form of Fourteenth Supplemental Indenture, dated May 1, 2007 (Exhibit 4.2, Form 8-K filed May 16, 2007, File No. 1-2255); Form of Fifteenth Supplemental Indenture, dated September 1, 2007 (Exhibit 4.2, Form 8-K filed September 10, 2007, File No. 1-2255); Forms of Sixteenth and Seventeenth Supplemental Indentures, dated November 1, 2007 (Exhibits 4.2 and 4.3, Form 8-K filed November 30, 2007, File No. 1-2255); Form of Eighteenth Supplemental Indenture, dated April 1, 2008 (Exhibit 4.2, Form 8-K filed April 15, 2008, File No. 1-2255); Form of Nineteenth Supplemental and Amending Indenture, dated November 1, 2008 (Exhibit 4.2, Form 8-K filed November 5, 2008, File No. 1-2255); Form of Twentieth Supplemental Indenture, dated June 1, 2009 (Exhibit 4.3, Form 8-K filed June 24, 2009, File No. 1-2255); and Twenty-First Supplemental Indenture, dated August 1, 2010 (Exhibit 4.3, Form 8-K filed September 1, 2010, File No. 1-2255).		X
10.1	$3.0 billion Three-Year Revolving Credit Agreement, dated September 24, 2010, among Dominion Resources, Inc., Virginia Electric and Power Company, JP Morgan Chase Bank, N.A., as Administrative Agent, Bank of America, N.A., Barclays Capital, The Royal Bank of Scotland plc, and Wells Fargo Bank, N.A., as Syndication Agents and other lenders named therein (Exhibit 10.1, Form 8-K filed September 28, 2010, File No. 1-8489 and File No. 1-2255).	X	X
10.2	$500,000,000 Three-Year Revolving Credit Agreement, dated September 24, 2010, among Dominion Resources, Inc., Virginia Electric and Power Company, Keybank National Association, as Administrative Agent, Bayerische Landesbank, New York Branch, and U.S. Bank National Association, as Syndication Agents, and other lenders named therein (Exhibit 10.2, Form 8-K filed September 28, 2010, File No. 1-8489 and File No. 1-2255).	X	X
12.1	Ratio of earnings to fixed charges for Dominion Resources, Inc. (filed herewith).	X
12.2a	Ratio of earnings to fixed charges for Virginia Electric and Power Company (filed herewith).		X
12.2b	Ratio of earnings to fixed charges and preferred dividends for Virginia Electric and Power Company (filed herewith).		X
31.a	Certification by Chief Executive Officer of Dominion Resources, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).	X
31.b	Certification by Chief Financial Officer of Dominion Resources, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).	X
31.c	Certification by Chief Executive Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X
31.d	Certification by Chief Financial Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X
32.a	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion Resources, Inc. as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).	X
32.b	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Virginia Electric and Power Company as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).		X
99	Condensed consolidated earnings statements (filed herewith).	X	X

PAGE 70

Exhibit Number	Description	Dominion	Virginia Power
101^	The following financial statements from Dominion Resources, Inc. and Virginia Electric and Power Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2010, filed on October 29, 2010, formatted in XBRL: (i) Consolidated Statements of Income; (ii) Consolidated Balance Sheets; (iii) Consolidated Statements of Cash Flows; and (iv) the Notes to Consolidated Financial Statements.	X	X

^ This exhibit will not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934 (15 U.S.C. 78r), or otherwise subject to the liability of that section. Such exhibit will not be deemed to be incorporated by reference into any filing under the Securities Act or Securities Exchange Act, except to the extent that one of the Companies specifically incorporates it by reference.

PAGE 71

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
October 29, 2010	/s/ Ashwini Sawhney
	Ashwini Sawhney Vice President – Accounting and Controller (Chief Accounting Officer)
	VIRGINIA ELECTRIC AND POWER COMPANY Registrant
October 29, 2010	/s/ Ashwini Sawhney
	Ashwini Sawhney Vice President – Accounting (Chief Accounting Officer)

PAGE 72

EXHIBIT INDEX

Exhibit Number	Description	Dominion	Virginia Power
3.1.a	Dominion Resources, Inc. Articles of Incorporation as amended and restated effective May 20, 2010 (Exhibit 3.1, Form 8-K filed May 20, 2010, File No. 1-8489).	X
3.1.b	Virginia Electric and Power Company Restated Articles of Incorporation, as in effect on October 28, 2003 (Exhibit 3.1, Form 10-Q for the quarter ended September 30, 2003 filed November 7, 2003, File No. 1-2255).		X
3.2.a	Dominion Resources, Inc. Bylaws, as amended and restated effective May 18, 2010 (Exhibit 3.2, Form 8-K filed May 20, 2010, File No. 1-8489)	X
3.2.b	Virginia Electric and Power Company Amended and Restated Bylaws, effective June 1, 2009 (Exhibit 3.1, Form 8-K filed June 3, 2009, File No. 1-2255).		X
4	Dominion Resources, Inc. and Virginia Electric and Power Company agree to furnish to the Securities and Exchange Commission upon request any other instrument with respect to long-term debt as to which the total amount of securities authorized does not exceed 10% of either of their total consolidated assets.	X	X
4.1	Form of Senior Indenture, dated June 1, 2000, between Dominion Resources, Inc. and The Bank of New York Mellon (as successor trustee to JP Morgan Chase Bank (formerly The Chase Manhattan Bank)), as Trustee (Exhibit 4(iii), Form S-3 Registration Statement filed December 21, 1999, File No. 333-93187); Form of First Supplemental Indenture, dated June 1, 2000 (Exhibit 4.2, Form 8-K filed June 22, 2000, File No. 1-8489); Forms of Second and Third Supplemental Indentures, dated July 1, 2000 (Exhibits 4.2 and 4.3, Form 8-K filed July 11, 2000, File No. 1-8489); Fourth Supplemental Indenture, dated September 1, 2000 (Exhibit 4.2, Form 8-K filed September 8, 2000, File No. 1-8489); Sixth Supplemental Indenture, dated September 1, 2000 (Exhibit 4.3, Form 8-K filed September 11, 2000, File No. 1-8489); Form of Seventh Supplemental Indenture, dated October 1, 2000 (Exhibit 4.2, Form 8-K filed October 12, 2000, File No. 1-8489); Form of Eighth Supplemental Indenture, dated January 1, 2001 (Exhibit 4.2, Form 8-K filed January 24, 2001, File No. 1-8489); Form of Ninth Supplemental Indenture, dated May 1, 2001 (Exhibit 4.4, Form 8-K filed May 25, 2001, File No. 1-8489); Form of Tenth Supplemental Indenture, dated March 1, 2002 (Exhibit 4.2, Form 8-K filed March 18, 2002, File No. 1-8489); Form of Eleventh Supplemental Indenture, dated June 1, 2002 (Exhibit 4.2, Form 8-K filed June 25, 2002, File No. 1- 8489); Form of Twelfth Supplemental Indenture, dated September 1, 2002 (Exhibit 4.2, Form 8-K filed September 11, 2002, File No. 1-8489); Thirteenth Supplemental Indenture, dated September 16, 2002 (Exhibit 4.1, Form 8-K filed September 17, 2002, File No. 1-8489); Fourteenth Supplemental Indenture, dated August 1, 2003 (Exhibit 4.4, Form 8-K filed August 20, 2003, File No. 1-8489); Forms of Fifteenth and Sixteenth Supplemental Indentures, dated December 1, 2002 (Exhibits 4.2 and 4.3, Form 8-K filed December 13, 2002, File No. 1-8489); Forms of Seventeenth and Eighteenth Supplemental Indentures, dated February 1, 2003 (Exhibits 4.2 and 4.3, Form 8-K filed February 11, 2003, File No. 1-8489; Forms of Twentieth and Twenty-First Supplemental Indentures, dated March 1, 2003 (Exhibits 4.2 and 4.3, Form 8-K filed March 4, 2003, File No. 1-8489); Form of Twenty-Second Supplemental Indenture, dated July 1, 2003 (Exhibit 4.2, Form 8-K filed July 22, 2003, File No. 1-8489); Form of Twenty-Third Supplemental Indenture, dated December 1, 2003 (Exhibit 4.2, Form 8-K filed December 10, 2003, File No. 1-8489); Forms of Twenty-Fifth and Twenty-Sixth Supplemental Indentures, dated January 1, 2004 (Exhibits 4.2 and 4.3, Form 8-K filed January 14, 2004, File No. 1-8489); Form of Twenty-Seventh Supplemental Indenture, dated December 1, 2004 (Exhibit 4.2, Form S-4 Registration Statement filed November 10, 2004, File No. 333-120339); Forms of Twenty-Eighth and Twenty-Ninth Supplemental Indentures, dated June 1, 2005 (Exhibits 4.2 and 4.3, Form 8-K filed June 17, 2005, File No. 1-8489); Form of Thirtieth Supplemental Indenture, dated July 1, 2005 (Exhibit 4.2, Form 8-K filed July 12, 2005, File No. 1-8489); Form of Thirty-First Supplemental Indenture, dated September 1, 2005 (Exhibit 4.2, Form 8-K filed September 26, 2005, File No. 1-8489); Forms of Thirty-Second and Thirty-Third Supplemental Indentures, dated November 1, 2006 (Exhibits 4.2 and 4.3, Form 8-K filed November 13, 2006, File No. 1-8489); Form of Thirty-Fourth Supplemental Indenture, dated November 1, 2007 (Exhibit 4.2, Form 8-K filed November 29, 2007, File No. 1-8489); Forms of Thirty-Fifth, Thirty-Sixth and Thirty-Seventh Supplemental Indentures, dated June 1, 2008 (Exhibits 4.2, 4.3 and 4.4, Form 8-K	X

PAGE 73

Exhibit Number	Description	Dominion	Virginia Power
	filed June 16, 2008, File No. 1-8489); Form of Thirty-Eighth Supplemental and Amending Indenture, dated November 1, 2008 (Exhibit 4.2, Form 8-K filed November 26, 2008, File No. 1-8489); Thirty-Ninth Supplemental Indenture Amending the Twenty-Seventh Supplemental Indenture, dated December 1, 2008 and effective as of December 16, 2008 (Exhibit 4.1, Form 8-K filed December 5, 2008, File No. 1-8489); Form of Thirty-Ninth Supplemental Indenture, dated August 1, 2009 (Exhibit 4.3, Form 8-K filed August 12, 2009, File No. 1-8489); Fortieth Supplemental Indenture, dated August 1, 2010 (Exhibit 4.3, Form 8-K filed September 2, 2010, File No. 1-8489).
4.2	Form of Senior Indenture, dated June 1, 1998, between Virginia Electric and Power Company and The Bank of New York Mellon (as successor trustee to JP Morgan Chase Bank (formerly The Chase Manhattan Bank)), as Trustee (Exhibit 4(iii), Form S-3 Registration Statement filed February 27, 1998, File No. 333-47119); Form of First Supplemental Indenture, dated June 1, 1998 (Exhibit 4.2, Form 8-K filed June 12, 1998, File No. 1-2255); Form of Second Supplemental Indenture, dated June 1, 1999 (Exhibit 4.2, Form 8-K filed June 4, 1999, File No. 1-2255); Form of Third Supplemental Indenture, dated November 1, 1999 (Exhibit 4.2, Form 8-K filed October 27, 1999, File No. 1-2255); Forms of Fourth and Fifth Supplemental Indentures, dated March 1, 2001 (Exhibits 4.2 and 4.3, Form 8-K filed March 26, 2001, File No. 1-2255); Form of Sixth Supplemental Indenture, dated January 1, 2002 (Exhibit 4.2, Form 8-K filed January 29, 2002, File No. 1-2255); Seventh Supplemental Indenture, dated September 1, 2002 (Exhibit 4.4, Form 8-K filed September 11, 2002, File No. 1-2255); Form of Eighth Supplemental Indenture, dated February 1, 2003 (Exhibit 4.2, Form 8-K filed February 27, 2003, File No. 1-2255); Forms of Ninth and Tenth Supplemental Indentures, dated December 1, 2003 (Exhibits 4.2 and 4.3, Form 8-K filed December 4, 2003, File No. 1-2255); Form of Eleventh Supplemental Indenture, dated December 1, 2003 (Exhibit 4.2, Form 8-K filed December 11, 2003, File No. 1-2255); Forms of Twelfth and Thirteenth Supplemental Indentures, dated January 1, 2006 (Exhibits 4.2 and 4.3, Form 8-K filed January 12, 2006, File No. 1-2255); Form of Fourteenth Supplemental Indenture, dated May 1, 2007 (Exhibit 4.2, Form 8-K filed May 16, 2007, File No. 1-2255); Form of Fifteenth Supplemental Indenture, dated September 1, 2007 (Exhibit 4.2, Form 8-K filed September 10, 2007, File No. 1-2255); Forms of Sixteenth and Seventeenth Supplemental Indentures, dated November 1, 2007 (Exhibits 4.2 and 4.3, Form 8-K filed November 30, 2007, File No. 1-2255); Form of Eighteenth Supplemental Indenture, dated April 1, 2008 (Exhibit 4.2, Form 8-K filed April 15, 2008, File No. 1-2255); Form of Nineteenth Supplemental and Amending Indenture, dated November 1, 2008 (Exhibit 4.2, Form 8-K filed November 5, 2008, File No. 1-2255); Form of Twentieth Supplemental Indenture, dated June 1, 2009 (Exhibit 4.3, Form 8-K filed June 24, 2009, File No. 1-2255); and Twenty-First Supplemental Indenture, dated August 1, 2010 (Exhibit 4.3, Form 8-K filed September 1, 2010, File No. 1-2255).		X
10.1	$3.0 billion Three-Year Revolving Credit Agreement, dated September 24, 2010, among Dominion Resources, Inc., Virginia Electric and Power Company, JP Morgan Chase Bank, N.A., as Administrative Agent, Bank of America, N.A., Barclays Capital, The Royal Bank of Scotland plc, and Wells Fargo Bank, N.A., as Syndication Agents and other lenders named therein (Exhibit 10.1, Form 8-K filed September 28, 2010, File No. 1-8489 and File No. 1-2255).	X	X
10.2	$500,000,000 Three-Year Revolving Credit Agreement, dated September 24, 2010, among Dominion Resources, Inc., Virginia Electric and Power Company, Keybank National Association, as Administrative Agent, Bayerische Landesbank, New York Branch, and U.S. Bank National Association, as Syndication Agents, and other lenders named therein (Exhibit 10.2, Form 8-K filed September 28, 2010, File No. 1-8489 and File No. 1-2255).	X	X
12.1	Ratio of earnings to fixed charges for Dominion Resources, Inc. (filed herewith).	X
12.2a	Ratio of earnings to fixed charges for Virginia Electric and Power Company (filed herewith).		X
12.2b	Ratio of earnings to fixed charges and preferred dividends for Virginia Electric and Power Company (filed herewith)		X
31.a	Certification by Chief Executive Officer of Dominion Resources, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).	X
31.b	Certification by Chief Financial Officer of Dominion Resources, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).	X

PAGE 74

Exhibit Number	Description	Dominion	Virginia Power
31.c	Certification by Chief Executive Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X
31.d	Certification by Chief Financial Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X
32.a	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion Resources, Inc. as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).	X
32.b	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Virginia Electric and Power Company as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).		X
99	Condensed consolidated earnings statements (filed herewith).	X	X
101	The following financial statements from Dominion Resources, Inc. and Virginia Electric and Power Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2010, filed on October 29, 2010, formatted in XBRL: (i) Consolidated Statements of Income; (ii) Consolidated Balance Sheets; (iii) Consolidated Statements of Cash Flows; and (iv) the Notes to Consolidated Financial Statements.	X

PAGE 75

EX-12.1

Exhibit 12.1

Dominion Resources Inc. and Subsidiaries

Computation of Ratio of Earnings to Fixed Charges

(millions of dollars)

							Years Ended December 31,
	Nine Months Ended September  30, 2010 (a)			Twelve Months Ended September  30, 2010 (b)			2009 (c)			2008(d)			2007(e)			2006(f)			2005(g)
Earnings, as defined:
Income from continuing operations including noncontrolling interest before income taxes, extraordinary item and cumulative effect of change in accounting principle	$	4,472		$	4,225		$	1,874		$	2,613		$	4,442		$	2,609		$	1,561
Distributed income from unconsolidated investees, less equity in earnings		(33	)		(33	)		(30	)		(39	)		(20	)		(16	)		(15	)
Fixed charges, as defined		701			970			1,022			990			1,325			1,271			1,099
Capitalized interest		(19	)		(24	)		(18	)		(44	)		(73	)		(118	)		(96	)
Preference security dividend requirement of consolidated subsidiary		(21	)		(27	)		(24	)		(26	)		(26	)		(24	)		(24	)
Total earnings, as defined	$	5,100		$	5,111		$	2,824		$	3,494		$	5,648		$	3,722		$	2,525
Fixed charges, as defined:
Interest charges	$	638		$	886		$	941		$	911		$	1,238		$	1,190		$	1,023
Preference security dividend requirement of consolidated subsidiary		21			27			24			26			26			24			24
Rental interest factor		42			57			57			53			61			57			52
Total fixed charges, as defined	$	701		$	970		$	1,022		$	990		$	1,325		$	1,271		$	1,099
Ratio of Earnings to Fixed Charges		7.28			5.27			2.76			3.53			4.26			2.93			2.30

(a) Earnings for the nine months ended September 30, 2010 include a $2.4 billion benefit resulting from the sale of our Appalachian E&P operations - primarily reflecting the gain on the sale partially offset by certain transaction costs and other related charges. Earnings for the period also include a $338 million charge related to the workforce reduction program primarily reflecting severance pay and other benefits to affected employees and a $163 million charge related to our State Line coal-fired merchant power stations and a $7 million net charge related to other items. Excluding these items from the calculation would result in a lower ratio of earnings to fixed charges for the nine months ended September 30, 2010.

(b) Earnings for the twelve months ended September 30, 2010 include a $2.4 billion benefit resulting from the sale of our Appalachian E&P operations - primarily reflecting the gain on the sale partially offset by certain transaction costs and other related charges and an $18 million net gain related to our investments in nuclear decommissioning trust funds. Earnings for the period also include a $712 million charge in connection with the proposed settlement of Virginia Power’s 2009 rate case proceeding, a $338 million charge related to the workforce reduction program primarily reflecting severance pay and other

benefits to affected employees, a $163 million charge related to our State Line coal-fired merchant power stations and a $23 million net charge related to other items. Excluding these items from the calculation would result in a lower ratio of earnings to fixed charges for the twelve months ended September 30, 2010.

(c) Earnings for the twelve months ended December 31, 2009 include a $455 million impairment charge as a result of the quarterly ceiling test performed on our gas and oil properties under the full cost method of accounting, a $712 million charge in connection with the proposed settlement of Virginia Power’s 2009 rate case proceeding and a $41 million net charge related to other items. Earnings for the period also include a $103 million reduction in other operation and maintenance expense due to a downward revision in the nuclear decommissioning asset retirement obligation for a power station that is no longer in service. Excluding these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2009.

(d) Earnings for the twelve months ended December 31, 2008 include $180 million of impairment charges reflecting other-than-temporary declines in the fair value of securities held in nuclear decommissioning trust funds, $59 million of impairment charges related to Dominion Capital, Inc. (DCI) assets, a $42 million reduction in the gain recognized in 2007 from the sale of the majority of our U.S. exploration and production (E&P) businesses as a result of post-closing adjustments, and a $30 million net charge related to other items. Excluding these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2008.

(e) Earnings for the twelve months ended December 31, 2007 include a $3.6 billion gain from the disposition of the majority of our U.S. E&P operations, partially offset by $1 billion of charges related to the disposition which are comprised of $541 million related to the discontinuance of hedge accounting for certain gas and oil derivatives and subsequent changes in the fair value of these derivatives, $171 million primarily related to the settlement of volumetric production payment agreements, $242 million of charges related to the early retirement of debt, and $91 million of employee-related expenses. Earnings for the period also include a $387 million charge related to the impairment of the partially-completed Dresden generation facility; a $231 million charge due to the termination of a power sales agreement at our State Line generating facility; $88 million of impairment charges related to DCI assets; $48 million of charges related to litigation reserves, and $70 million of charges related to other items. Fixed charges for the twelve months ended December 31, 2007 include $234 million of costs related to the early retirement of debt associated with our debt tender offer completed in July 2007. Excluding these items from the calculation would result in a lower ratio of earnings to fixed charges for the twelve months ended December 31, 2007.

(f) Earnings for the twelve months ended December 31, 2006 include $90 million of impairment charges related to DCI assets, a $60 million charge due to an adjustment eliminating the application of hedge accounting related to certain interest rate swaps associated with our junior subordinated notes payable to affiliated trusts, a $27 million charge resulting from the termination of a pipeline project in West Virginia, a $26 million impairment charge resulting from a change in method of assessing other-than-temporary decline in the fair value of certain securities, $17 million of incremental charges related to hurricanes Katrina and Rita, and $12 million of net charges related to other items. Fixed charges for the twelve months ended December 31, 2006 include a $60 million charge due to an adjustment eliminating the application of hedge accounting related to certain interest rate swaps associated with our junior subordinated notes payable to affiliated trusts. Excluding these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2006.

(g) Earnings for the twelve months ended December 31, 2005 include a $423 million charge reflecting the de-designation of hedge contracts resulting from the delay of natural gas and oil production following Hurricanes Katrina and Rita, $73 million in charges resulting from the termination of certain long-term power purchase contracts, $21 million in net charges related to trading activities discontinued in 2004, including the Batesville long-term power-tolling contract divested in the second quarter of 2005 and other activities, $35 million of impairment charges related to DCI assets, a $76 million charge related to miscellaneous asset impairments, a $28 million charge related to expenses following Hurricanes Katrina and Rita and $5 million of charges related to other items. Excluding these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2005.

EX-12.2.A

Exhibit 12.2a

Virginia Electric and Power Company

Computation of Ratio of Earnings to Fixed Charges

(millions of dollars)

					Years Ended December 31,
	Nine Months Ended September  30, 2010		Twelve Months Ended September 30, 2010		2009		2008		2007			2006			2005
Earnings, as defined:
Income from continuing operations before income taxes, extraordinary item and cumulative effect of change in accounting principle	$	1,214	$	660	$	503	$	1,364	$	977		$	762		$	754
Fixed charges as defined		285		384		392		343		332			322			339
Capitalized interest		—		—		—		—		(4	)		(9	)		(6	)
Total earnings, as defined	$	1,499	$	1,044	$	895	$	1,707	$	1,305		$	1,075		$	1,087
Fixed charges, as defined:
Interest charges	$	273	$	368	$	376	$	330	$	320		$	311		$	329
Rental interest factor		12		16		16		13		12			11			10
Total fixed charges, as defined	$	285	$	384	$	392	$	343	$	332		$	322		$	339
Ratio of Earnings to Fixed Charges		5.26		2.72		2.28		4.98		3.93			3.34			3.21

EX-12.2.B

Exhibit 12.2b

Virginia Electric and Power Company

Computation of Ratio of Earnings to Fixed Charges and Preferred Dividends

(millions of dollars)

							Years Ended December 31,
	Nine Months Ended September  30, 2010			Twelve Months Ended September 30, 2010			2009			2008			2007			2006			2005
Earnings, as defined:
Income from continuing operations before income taxes, extraordinary item and cumulative effect of change in accounting principle	$	1,214		$	660		$	503		$	1,364		$	977		$	762		$	754
Fixed charges as defined		305			410			416			369			357			347			364
Capitalized interest		—			—			—			—			(4	)		(9	)		(6	)
Preference security dividend requirement		(20	)		(26	)		(24	)		(26	)		(25	)		(25	)		(25	)
Total earnings, as defined	$	1,499		$	1,044		$	895		$	1,707		$	1,305		$	1,075		$	1,087
Fixed charges, as defined:
Interest charges	$	273		$	368		$	376		$	330		$	320		$	311		$	329
Preference security dividend requirement		20			26			24			26			25			25			25
Rental interest factor		12			16			16			13			12			11			10
Total fixed charges, as defined	$	305		$	410		$	416		$	369		$	357		$	347		$	364
Ratio of Earnings to Fixed Charges and Preferred Dividends		4.91			2.55			2.15			4.63			3.66			3.10			2.99

EX-31.A

Exhibit 31.a

I, Thomas F. Farrell, II, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Resources, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: October 29, 2010	/s/ Thomas F. Farrell, II
	Thomas F. Farrell, II President and Chief Executive Officer

EX-31.B

Exhibit 31.b

I, Mark F. McGettrick, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Resources, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: October 29, 2010	/s/ Mark F. McGettrick
	Mark F. McGettrick Executive Vice President and Chief Financial Officer

EX-31.C

Exhibit 31.c

I, Thomas F. Farrell, II, certify that:

1. I have reviewed this report on Form 10-Q of Virginia Electric and Power Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: October 29, 2010	/s/ Thomas F. Farrell, II
	Thomas F. Farrell, II Chief Executive Officer

EX-31.D

Exhibit 31.d

I, Mark F. McGettrick, certify that:

1. I have reviewed this report on Form 10-Q of Virginia Electric and Power Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: October 29, 2010	/s/ Mark F. McGettrick
	Mark F. McGettrick Executive Vice President and Chief Financial Officer

EX-32.A

Exhibit 32.a

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned officers of Dominion Resources, Inc. (the Company), certify that:

1. the Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (the “Report”) of the Company to which this certification is an exhibit fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)).

2. the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of September 30, 2010 and for the period then ended.

/s/ Thomas F. Farrell, II

Thomas F. Farrell, II

President and Chief Executive Officer

October 29, 2010

/s/ Mark F. McGettrick

Mark F. McGettrick

Executive Vice President and

Chief Financial Officer

October 29, 2010

EX-32.B

Exhibit 32.b

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned officers of Virginia Electric and Power Company (the Company), certify that:

1. the Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (the “Report”) of the Company to which this certification is an exhibit fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)).

2. the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of September 30, 2010 and for the period then ended.

/s/ Thomas F. Farrell, II

Thomas F. Farrell, II

Chief Executive Officer

October 29, 2010

/s/ Mark F. McGettrick

Mark F. McGettrick

Executive Vice President and

Chief Financial Officer

October 29, 2010

EX-99

Exhibit 99

DOMINION RESOURCES, INC.

CONDENSED CONSOLIDATED EARNINGS STATEMENT

(Unaudited)

	Twelve Months Ended September 30, 2010
(millions, except per share amounts)
Operating Revenue	$	14,627
Operating Expenses		9,736
Income from operations		4,891
Other income		167
Interest and related charges		833
Income before income tax expense including noncontrolling interests	$	4,225
Income tax expense		1,632
Net income including noncontrolling interests		2,593
Loss from discontinued operations (including income tax benefit of $45)		(74	)
Noncontrolling interests		17
Net income attributable to Dominion	$	2,502
Amounts attributable to Dominion:
Income from continuing operations	$	2,576
Loss from discontinued operations		(74	)
Net income attributable to Dominion	$	2,502
Earnings Per Common Share – Basic
Income from continuing operations	$	4.37
Loss from discontinued operations		(0.12	)
Noncontrolling interests		(0.03	)
Net income attributable to Dominion	$	4.22
Earnings Per Common Share – Diluted
Income from continuing operations	$	4.36
Loss from discontinued operations		(0.12	)
Noncontrolling interests		(0.03	)
Net income attributable to Dominion	$	4.21

VIRGINIA ELECTRIC AND POWER COMPANY

CONDENSED CONSOLIDATED EARNINGS STATEMENT

(Unaudited)

	Twelve Months Ended September 30, 2010
(millions)
Operating Revenue	$	6,673
Operating Expenses		5,774
Income from operations		899
Other income		106
Interest and related charges		345
Income before income tax expense		660
Income tax expense		230
Net Income		430
Preferred dividends		17
Balance available for common stock	$	413