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 March 31, 2012

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  x    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 March 31, 2012, the latest practicable date for determination, Dominion Resources, Inc. had 571,498,534 shares of common stock outstanding and Virginia Electric and Power Company had 274,723 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		PAGE 3
	PART I. Financial Information
Item 1.	Financial Statements		PAGE 6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		PAGE 49
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		PAGE 63
Item 4.	Controls and Procedures		PAGE 64
	PART II. Other Information
Item 1.	Legal Proceedings		PAGE 64
Item 1A.	Risk Factors		PAGE 65
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		PAGE 65
Item 6.	Exhibits		PAGE 66

PAGE 2

GLOSSARY OF TERMS

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

Abbreviation or Acronym	Definition
2009 Base Rate Review	Order entered by the Virginia Commission in January 2009, pursuant to the Regulation Act, initiating reviews of the base rates and terms and conditions of all investor-owned utilities in Virginia
AFUDC	Allowance for funds used during construction
AOCI	Accumulated other comprehensive income (loss)
ARO	Asset retirement obligation
ARP	Acid Rain Program, a market-based initiative for emissions allowance trading, established pursuant to Title IV of the CAA
bcf	Billion cubic feet
Bear Garden	A 590 MW combined cycle, natural gas-fired power station in Buckingham County, Virginia
Biennial Review Order	Order issued by the Virginia Commission in November 2011 concluding the 2009 - 2010 biennial review of Virginia Power’s base rates, terms and conditions
Brayton Point	Brayton Point power station
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
CEO	Chief Executive Officer
CERCLA	Comprehensive Environmental Response, Compensation and Liability Act of 1980
CFO	Chief Financial Officer
CFTC	Commodity Futures Trading Commission
CO2	Carbon dioxide
Companies	Dominion and Virginia Power, collectively
Cooling degree days	Units measuring the extent to which the average daily temperature is greater than 65 degrees Fahrenheit, calculated as the difference between 65 degrees and the average temperature for that day
Cove Point	Dominion Cove Point LNG, LP
CSAPR	Cross State Air Pollution Rule
CWA	Clean Water Act
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
DRS	Dominion Resources Services, Inc.
Dth	Dekatherm
DVP	Dominion Virginia Power operating segment
East Ohio	The East Ohio Gas Company, doing business as Dominion East Ohio
EPA	Environmental Protection Agency
EPS	Earnings per share
ERM	Enterprise Risk Management
Fairless	Fairless power station
FCM	Futures Commission Merchant
FERC	Federal Energy Regulatory Commission
Fowler Ridge	A wind-turbine facility joint venture between Dominion and BP Alternative Energy, Inc. in Benton County, Indiana
FTRs	Financial transmission rights
GAAP	U.S. generally accepted accounting principles
Gal	Gallon
GHG	Greenhouse gas

PAGE 3

Abbreviation or Acronym	Definition
Heating degree days	Units measuring the extent to which the average daily temperature is less than 65 degrees Fahrenheit, calculated as the difference between 65 degrees and the average temperature for that day
INPO	Institute of Nuclear Power Operations
ISO	Independent system operator
Kewaunee	Kewaunee nuclear power station
Kincaid	Kincaid power station
LNG	Liquefied natural gas
Manchester Street	Manchester Street power station
MATS	Utility Mercury and Air Toxics Standard Rule
MD&A	Management’s Discussion and Analysis of Financial Condition and Results of Operations
MF Global	MF Global Inc.
Millstone	Millstone nuclear power station
Moody’s	Moody’s Investors Service
MW	Megawatt
MWh	Megawatt hour
NCEMC	North Carolina Electric Membership Corporation
NedPower	A wind-turbine facility joint venture between Dominion and Shell WindEnergy Inc. in Grant County, West Virginia
NGLs	Natural gas liquids
North Anna	North Anna nuclear power station
North Carolina Commission	North Carolina Utilities Commission
NOx	Nitrogen oxide
NPDES	National Pollutant Discharge Elimination System
NRC	Nuclear Regulatory Commission
NSPS	New Source Performance Standards
ODEC	Old Dominion Electric Cooperative
Ohio Commission	Public Utilities Commission of Ohio
OPEB	Other Postretirement Employee Benefits
PIR	Pipeline Infrastructure Replacement program deployed by East Ohio
PJM	PJM Interconnection, LLC
RCC	Replacement Capital Covenants
Regulation Act	Legislation effective July 1, 2007, that amended the Virginia Electric Utility Restructuring Act and fuel factor statute, which legislation is also known as the Virginia Electric Utility Regulation Act
RGGI	Regional Greenhouse Gas Initiative
Rider B	A rate adjustment clause associated with the recovery of costs related to the proposed conversion of three of Virginia Power’s coal-fired power stations to biomass
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
ROE	Return on equity
RPS	Renewable Portfolio Standard
RTO	Regional transmission organization
Salem Harbor	Salem Harbor power station
SEC	Securities and Exchange Commission
September 2006 hybrids	2006 Series B Enhanced Junior Subordinated Notes due 2066
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

PAGE 4

Abbreviation or Acronym	Definition
U.S.	United States of America
UAO	Unilateral Administrative Order
VIE	Variable interest entity
Virginia City Hybrid Energy Center	A 585 MW baseload carbon-capture compatible, clean coal powered electric generation facility under construction in Wise County, Virginia
Virginia Commission	Virginia State Corporation Commission
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
Virginia Settlement Approval Order	Order issued by the Virginia Commission in March 2010 concluding Virginia Power’s 2009 Base Rate Review

PAGE 5

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended March 31,
	2012		2011
(millions, except per share amounts)
Operating Revenue	$	3,492	$	4,057
Operating Expenses
Electric fuel and other energy-related purchases		948		1,049
Purchased electric capacity		113		119
Purchased gas		412		642
Other operations and maintenance		647		861
Depreciation, depletion and amortization		287		262
Other taxes		170		161
Total operating expenses		2,577		3,094
Income from operations		915		963
Other income		74		57
Interest and related charges		228		227
Income from operations including noncontrolling interests before income tax expense		761		793
Income tax expense		260		310
Net Income Including Noncontrolling Interests		501		483
Noncontrolling Interests		7		4
Net Income Attributable to Dominion	$	494	$	479
Amounts Attributable to Dominion:
Earnings Per Common Share – Basic	$	0.87	$	0.83
Earnings Per Common Share – Diluted	$	0.86	$	0.82
Dividends declared per common share	$	0.5275	$	0.4925

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

PAGE 6

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
	2012			2011
(millions)
Net income including noncontrolling interests	$	501		$	483
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of $(80) and $58 tax		128			(85	)
Changes in unrealized net gains on investment securities, net of $(56) and $(25) tax		85			38
Changes in net unrecognized pension and other postretirement benefit costs, net of $— and $(15) tax		—			25
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of $12 and $(5) tax		(16	)		13
Net realized gains on investment securities, net of $6 and $2 tax		(10	)		(2	)
Net pension and other postretirement benefit costs, net of $(9) and $(2) tax		12			14
Total other comprehensive income		199			3
Comprehensive income including noncontrolling interests		700			486
Comprehensive income attributable to noncontrolling interests		7			4
Comprehensive income attributable to Dominion	$	693		$	482

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

PAGE 7

DOMINION RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2012			December  31, 2011(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	133		$	102
Customer receivables (less allowance for doubtful accounts of $29 at both dates)		1,539			1,780
Other receivables (less allowance for doubtful accounts of $5 and $8)		173			255
Inventories		1,249			1,348
Derivative assets		822			705
Other		1,103			1,240
Total current assets		5,019			5,430
Investments
Nuclear decommissioning trust funds		3,231			2,999
Investment in equity method affiliates		552			553
Restricted cash equivalents		104			141
Other		296			292
Total investments		4,183			3,985
Property, Plant and Equipment
Property, plant and equipment		42,895			42,033
Property, plant and equipment, VIE		957			957
Accumulated depreciation, depletion and amortization		(13,564	)		(13,320	)
Total property, plant and equipment, net		30,288			29,670
Deferred Charges and Other Assets
Goodwill		3,141			3,141
Regulatory assets		1,319			1,382
Other		2,143			2,006
Total deferred charges and other assets		6,603			6,529
Total assets	$	46,093		$	45,614

(1) Dominion’s Consolidated Balance Sheet at December 31, 2011 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 8

DOMINION RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	March 31, 2012			December  31, 2011(1)
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	2,131		$	1,479
Short-term debt		1,057			1,814
Accounts payable		935			1,250
Derivative liabilities		871			951
Other		1,660			1,468
Total current liabilities		6,654			6,962
Long-Term Debt
Long-term debt		14,564			14,785
Long-term debt, VIE		882			890
Junior subordinated notes payable to affiliates		268			268
Enhanced junior subordinated notes		1,365			1,451
Total long-term debt		17,079			17,394
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		5,719			5,216
Asset retirement obligations		1,396			1,383
Regulatory liabilities		1,423			1,324
Other		1,596			1,575
Total deferred credits and other liabilities		10,134			9,498
Total liabilities		33,867			33,854
Commitments and Contingencies (see Note 12)
Subsidiary Preferred Stock Not Subject to Mandatory Redemption		257			257
Equity
Common stock – no par(2)		5,256			5,180
Other paid-in capital		173			179
Retained earnings		6,891			6,697
Accumulated other comprehensive loss		(411	)		(610	)
Total common shareholders’ equity		11,909			11,446
Noncontrolling interest		60			57
Total equity		11,969			11,503
Total liabilities and equity	$	46,093		$	45,614

(1) Dominion’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

(2) 1 billion shares authorized; 571 million shares and 570 million shares outstanding at March 31, 2012 and December 31, 2011, respectively.

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

PAGE 9

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

Three Months Ended March 31,	2012			2011
(millions)
Operating Activities
Net income including noncontrolling interests	$	501		$	483
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)		353			318
Deferred income taxes and investment tax credits		269			227
Rate refunds		(55	)		(29	)
Other adjustments		(72	)		(17	)
Changes in:
Accounts receivable		327			292
Inventories		99			119
Deferred fuel and purchased gas costs, net		162			(50	)
Prepayments		37			54
Accounts payable		(275	)		(299	)
Accrued interest, payroll and taxes		89			(129	)
Margin deposit assets and liabilities		97			(120	)
Other operating assets and liabilities		91			63
Net cash provided by operating activities		1,623			912
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(981	)		(806	)
Proceeds from sales of securities		415			502
Purchases of securities		(420	)		(522	)
Restricted cash equivalents		37			56
Other		3			18
Net cash used in investing activities		(946	)		(752	)
Financing Activities
Repayment of short-term debt, net		(757	)		(538	)
Issuance and remarketing of long-term debt		450			1,060
Repayment and repurchase of long-term debt		(104	)		(2	)
Issuance of common stock		69			17
Repurchase of common stock		—			(274	)
Common dividend payments		(301	)		(285	)
Subsidiary preferred dividend payments		(4	)		(4	)
Other		1			(8	)
Net cash used in financing activities		(646	)		(34	)
Increase in cash and cash equivalents		31			126
Cash and cash equivalents at beginning of period		102			62
Cash and cash equivalents at end of period	$	133		$	188
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures	$	298		$	167

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

PAGE 10

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended March 31,
	2012		2011
(millions)
Operating Revenue	$	1,754	$	1,757
Operating Expenses
Electric fuel and other energy-related purchases		614		593
Purchased electric capacity		113		118
Other operations and maintenance:
Affiliated suppliers		83		73
Other		223		229
Depreciation and amortization		188		174
Other taxes		65		59
Total operating expenses		1,286		1,246
Income from operations		468		511
Other income		23		29
Interest and related charges		100		92
Income before income tax expense		391		448
Income tax expense		148		170
Net Income		243		278
Preferred dividends		4		4
Balance available for common stock	$	239	$	274

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

PAGE 11

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
	2012			2011
(millions)
Net income	$	243		$	278
Other comprehensive income (loss), net of taxes:
Net deferred losses on derivatives-hedging activities, net of $— tax at both dates		(1	)		—
Changes in unrealized net gains on nuclear decommissioning trust funds, net of $(5) and $(2) tax		9			3
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of $(1) and $— tax		1			(1	)
Net realized gains on nuclear decommissioning trust funds, net of $1 and $— tax		(1	)		—
Other comprehensive income		8			2
Comprehensive income	$	251		$	280

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

PAGE 12

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2012			December 31, 2011(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	28		$	29
Customer receivables (less allowance for doubtful accounts of $11 at both dates)		789			892
Other receivables (less allowance for doubtful accounts of $4 and $7)		127			145
Inventories (average cost method)		777			797
Prepayments		29			41
Other		373			532
Total current assets		2,123			2,436
Investments
Nuclear decommissioning trust funds		1,467			1,370
Other		32			36
Total investments		1,499			1,406
Property, Plant and Equipment
Property, plant and equipment		29,136			28,626
Accumulated depreciation and amortization		(9,758	)		(9,615	)
Total property, plant and equipment, net		19,378			19,011
Deferred Charges and Other Assets
Intangible assets		185			183
Regulatory assets		345			399
Other		86			109
Total deferred charges and other assets		616			691
Total assets	$	23,616		$	23,544

(1) Virginia Power’s Consolidated Balance Sheet at December 31, 2011 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 13

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	March 31, 2012		December  31, 2011(1)
(millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Securities due within one year	$	1,016	$	616
Short-term debt		255		894
Accounts payable		395		405
Payables to affiliates		54		108
Affiliated current borrowings		187		187
Accrued interest, payroll and taxes		363		226
Other		520		685
Total current liabilities		2,790		3,121
Long-Term Debt		6,292		6,246
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		3,339		3,180
Asset retirement obligations		628		624
Regulatory liabilities		1,191		1,095
Other		270		271
Total deferred credits and other liabilities		5,428		5,170
Total liabilities		14,510		14,537
Commitments and Contingencies (see Note 12)
Preferred Stock Not Subject to Mandatory Redemption		257		257
Common Shareholder’s Equity
Common stock – no par(2)		5,738		5,738
Other paid-in capital		1,111		1,111
Retained earnings		1,973		1,882
Accumulated other comprehensive income		27		19
Total common shareholder’s equity		8,849		8,750
Total liabilities and shareholder’s equity	$	23,616	$	23,544

(1) Virginia Power’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

(2) 500,000 shares authorized; 274,723 shares outstanding at March 31, 2012 and December 31, 2011.

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

PAGE 14

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Three Months Ended March 31,	2012			2011
(millions)
Operating Activities
Net income	$	243		$	278
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		222			205
Deferred income taxes and investment tax credits		85			150
Rate refunds		(55	)		(29	)
Other adjustments		(20	)		(32	)
Changes in:
Accounts receivable		125			127
Affiliated accounts receivable and payable		(15	)		(31	)
Inventories		20			(42	)
Deferred fuel expenses		156			(32	)
Accounts payable		(59	)		(69	)
Accrued interest, payroll and taxes		137			25
Other operating assets and liabilities		67			(26	)
Net cash provided by operating activities		906			524
Investing Activities
Plant construction and other property additions		(483	)		(408	)
Purchases of nuclear fuel		(67	)		(49	)
Purchases of securities		(193	)		(362	)
Proceeds from sales of securities		191			343
Restricted cash equivalents		3			56
Other		(9	)		9
Net cash used in investing activities		(558	)		(411	)
Financing Activities
Repayment of short-term debt, net		(639	)		(18	)
Repayment of affiliated current borrowings, net		—			(44	)
Issuance and remarketing of long-term debt		450			160
Common dividend payments		(149	)		(130	)
Preferred dividend payments		(4	)		(4	)
Other		(7	)		(2	)
Net cash used in financing activities		(349	)		(38	)
Increase (decrease) in cash and cash equivalents		(1	)		75
Cash and cash equivalents at beginning of period		29			5
Cash and cash equivalents at end of period	$	28		$	80
Supplemental Cash Flow Information
Significant noncash investing and financing activities:
Accrued capital expenditures	$	208		$	121

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

PAGE 15

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.

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, 2011.

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 March 31, 2012 and their results of operations and cash flows for the three months ended March 31, 2012 and 2011. 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 and those VIEs where Dominion has been determined to be the primary beneficiary.

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 2011 Consolidated Financial Statements and Notes have been reclassified to conform to the 2012 presentation for comparative purposes. The reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows.

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

PAGE 16

Note 3. Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended March  31,
	2012		2011
(millions)
Dominion
Electric sales:
Regulated	$	1,724	$	1,730
Nonregulated		738		941
Gas sales:
Regulated		99		139
Nonregulated		398		602
Gas transportation and storage		405		538
Other		128		107
Total operating revenue	$	3,492	$	4,057
Virginia Power
Regulated electric sales	$	1,724	$	1,730
Other		30		27
Total operating revenue	$	1,754	$	1,757

Note 4. Income Taxes

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
Three Months Ended March 31,	2012			2011			2012			2011
U.S. statutory rate		35.0	%		35.0	%		35.0	%		35.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit		3.8			3.7			3.9			3.9
Valuation allowances		(2.7	)		0.8			—			—
AFUDC - equity		(0.7	)		(0.7	)		(0.9	)		(1.1	)
Other, net		(1.3	)		0.3			(0.2	)		0.2
Effective tax rate		34.1	%		39.1	%		37.8	%		38.0	%

Dominion’s effective tax rate in 2012 reflects a $20 million reduction of a valuation allowance related to certain state operating loss carryforwards. As disclosed in Note 16 to the Consolidated Financial Statements in its Annual Report on Form 10-K for the year ended December 31, 2011, Dominion expects to purchase Fairless in 2013. Dominion currently operates the facility under a lease and, as a result of a 2012 contract modification, the exercise price of Dominion’s option to purchase Fairless is fixed at approximately $923 million. After considering the results of Fairless’ operations in recent years and a forecast of future operating results reflecting the planned purchase of the facility, Dominion has concluded that it is more likely than not that the tax benefit of the operating losses will be realized. Significant assumptions include future commodity prices, in particular, those for electric energy produced by Fairless and those for natural gas, as compared to other fuels used for the generation of electricity, which will significantly influence the extent to which Fairless is dispatched by PJM. Realization of these tax benefits ultimately depends on whether or not the forecasted results are achieved. Dominion will continue to evaluate the likelihood of realizing these tax benefits on a quarterly basis.

As of March 31, 2012, there have been no material changes in Dominion’s and Virginia Power’s unrecognized tax benefits or possible changes that could reasonably be expected to occur during the next twelve months. See Note 6 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2011 for a discussion of these unrecognized tax benefits.

PAGE 17

Note 5. Earnings Per Share

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

	Three Months Ended March 31,
	2012		2011
(millions, except EPS)
Net income attributable to Dominion	$	494	$	479
Average shares of common stock outstanding – Basic		570.5		579.8
Net effect of potentially dilutive securities(1)		1.4		0.7
Average shares of common stock outstanding – Diluted		571.9		580.5
Earnings Per Common Share – Basic	$	0.87	$	0.83
Earnings Per Common Share – Diluted	$	0.86	$	0.82

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

There were no potentially dilutive securities excluded from the calculation of diluted EPS for the three months ended March 31, 2012 and 2011.

Note 6. 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, 2011. See Note 7 in this report for further information about their derivatives and hedge accounting activities.

At March 31, 2012, Dominion’s and Virginia Power’s net balance of commodity derivatives categorized as Level 3 fair value measurements was a net liability of $61 million and $17 million, respectively.

Dominion’s and Virginia Power’s commodity derivative valuations are prepared by the ERM department. The ERM department reports directly to the Companies’ CFO. The ERM department creates a daily computer-generated file containing mark-to-market valuations for the Companies’ derivative transactions. Standard transactions are programmatically calculated using software. The inputs that go into the mark-to-market valuations are transactional information stored in the systems of record and market pricing information that resides in data warehouse databases. The majority of forward prices are automatically uploaded into the data warehouse databases from various third party sources. Inputs obtained from third party sources are evaluated for reliability considering the reputation, independence, market presence, and methodology used by the third party. If forward prices are not available from third party sources, then the ERM department models the forward prices based on other available market data. A team consisting of risk management and risk quantitative analysts meets each business day to assess the validity of market prices and mark-to-market valuations. During this meeting, the changes in mark-to-market valuations from period to period are examined and qualified against historical expectations. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

Dominion and Virginia Power use the discounted cash flow method to value Level 3 physical and financial forwards and futures and an option model to value Level 3 physical and financial options. The discounted cash flow model calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, price correlations, the original sales prices, and volumes. For Level 3 fair value measurements, the forward market prices, the implied price volatilities, and price correlations are considered unobservable. The unobservable inputs are developed and substantiated using historical information, available market data, third party data, and statistical analysis. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources.

PAGE 18

The following table presents Dominion’s quantitative information about Level 3 fair value measurements. Included are descriptions of the valuation techniques, the significant unobservable inputs, and the range of market price, price correlation and price volatility inputs used in the fair value measurements at March 31, 2012 for each category of transaction and commodity type. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility and correlations.

	Fair Value (millions)		Valuation Technique(s)	Unobservable Input			Range			Weighted Average(1)
At March 31, 2012
Assets:
Physical and Financial Forwards and Futures:
Natural Gas(2)	$	31	Discounted Cash Flow		Market Price (per  Dth	) (3)		(1) - 6			3
Electricity		69	Discounted Cash Flow		Market Price (per  MWh	) (3)		21 - 61			43
FTRs		1	Discounted Cash Flow		Market Price (per  MWh	) (3)		(3) - 3			—
Capacity		9	Discounted Cash Flow		Market Price (per  MW	) (3)		95-120			101
Liquids		1	Discounted Cash Flow		Market Price (per  Gal	) (3)		1 - 2			1
Physical and Financial Options:
Natural Gas		6	Option Model		Market Price (per  Dth	) (3)		2 - 5			4
					Price Volatility	(4)		23% - 60	%		30	%
					Price Correlation	(5)		100% - 100	%		100	%
Total assets	$	117
Liabilities:
Physical and Financial Forwards and Futures:
Natural Gas(2)	$	21	Discounted Cash Flow		Market Price (per  Dth	) (3)		(1) - 6			3
Electricity		17	Discounted Cash Flow		Market Price (per  MWh	) (3)		12 - 61			41
FTRs		18	Discounted Cash Flow		Market Price (per  MWh	) (3)		(6) - 5			—
Liquids		108	Discounted Cash Flow		Market Price (per  Gal	) (3)		1 - 3			2
Physical and Financial Options:
Natural Gas(2)		14	Option Model		Market Price (per  Dth	) (3)		(1) - 5			2
					Price Volatility	(4)		23% - 59	%		36	%
					Price Correlation	(5)		70% - 100	%		90	%
Total liabilities	$	178

(1) Averages weighted by volume.

(2) Includes basis.

(3) Represents market prices beyond defined terms for Levels 1 & 2.

(4) Represents volatilities unrepresented in published markets.

(5) Represents intra-price correlations for which markets do not exist.

The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements. Included are descriptions of the valuation techniques, the significant unobservable inputs, and the range of market price inputs used in the fair value measurements at March 31, 2012 for each category of transaction and commodity type. The range and weighted average are presented in dollars for market price inputs.

PAGE 19

	Fair Value (millions)		Valuation Technique(s)	Unobservable Input			Range	Weighted Average(1)
At March 31, 2012
Assets:
Physical and Financial Forwards and Futures:
FTRs	$	1	Discounted Cash Flow		Market Price (per  MWh	)(2)	(3) - 3		0
Total assets	$	1
Liabilities:
Physical and Financial Forwards and Futures:
FTRs	$	18	Discounted Cash Flow		Market Price (per  MWh	)(2)	(6) - 3		0
Total liabilities	$	18

(1) Averages weighted by volume.

(2) Represents market prices beyond defined terms for Levels 1 & 2.

Sensitivity of the fair value measurements to changes in the significant unobservable inputs is as follows:

Significant Unobservable Inputs	Position	Change to Input	Impact on Fair Value Measurement
Market Price	Buy	Increase (decrease)	Gain (loss)
Market Price	Sell	Increase (decrease)	Loss (gain)
Price Volatility	Buy	Increase (decrease)	Gain (loss)
Price Volatility	Sell	Increase (decrease)	Loss (gain)
Price Correlation	Buy	Increase (decrease)	Loss (gain)
Price Correlation	Sell	Increase (decrease)	Gain (loss)

Non-recurring Fair Value Measurements

During March 2011, Dominion determined that it was unlikely that State Line would participate in the May 2011 PJM capacity base residual auction that would commit State Line’s capacity from June 2014 through May 2015. This determination reflected an expectation that margins for coal-fired generation will remain compressed in the 2014 and 2015 period in combination with the expectation that State Line may be impacted during the same time period by environmental regulations that would likely require significant capital expenditures. As a result, Dominion evaluated State Line for impairment since it was more likely than not that State Line would be retired before the end of its previously estimated useful life. As a result of this evaluation, Dominion recorded an impairment charge of $55 million ($39 million after-tax) reflected 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 less than $1 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 used the income approach (discounted cash flows) to estimate the fair value of State Line’s long-lived assets in the impairment test. 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. State Line was retired in March 2012.

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)
At March 31, 2012
Assets:
Derivatives:
Commodity	$	54	$	1,007	$	117	$	1,178
Interest rate		—		94		—		94
Investments(1):
Equity securities:
U.S.:
Large cap		1,933		—		—		1,933
Other		59		—		—		59
Non-U.S.:
Large cap		11		—		—		11
Fixed income:
Corporate debt instruments		—		317		—		317
U.S. Treasury securities and agency debentures		308		170		—		478
State and municipal		—		328		—		328
Other		—		20		—		20
Cash equivalents and other		—		82		—		82
Restricted cash equivalents		—		104		—		104
Total assets	$	2,365	$	2,122	$	117	$	4,604
Liabilities:
Derivatives:
Commodity	$	19	$	737	$	178	$	934
Interest rate		—		176		—		176
Total liabilities	$	19	$	913	$	178	$	1,110
At December 31, 2011
Assets:
Derivatives:
Commodity	$	44	$	828	$	93	$	965
Interest rate		—		105		—		105
Investments(1):
Equity securities:
U.S.:
Large cap		1,718		—		—		1,718
Other		51		—		—		51
Non-U.S.:
Large cap		10		—		—		10
Fixed income:
Corporate debt instruments		—		332		—		332
U.S. Treasury securities and agency debentures		277		181		—		458
State and municipal		—		329		—		329
Other		—		23		—		23
Cash equivalents and other		—		60		—		60
Restricted cash equivalents		—		141		—		141
Total assets	$	2,100	$	1,999	$	93	$	4,192
Liabilities:
Derivatives:
Commodity	$	10	$	714	$	164	$	888
Interest rate		—		269		—		269
Total liabilities	$	10	$	983	$	164	$	1,157

(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 March 31,
	2012			2011
(millions)
Beginning balance	$	(71	)	$	(50	)
Total realized and unrealized gains (losses):
Included in earnings		(35	)		14
Included in other comprehensive income (loss)		5			(94	)
Included in regulatory assets/liabilities		11			(21	)
Settlements		30			(16	)
Transfers out of Level 3		(1	)		4
Ending balance	$	(61	)	$	(163	)
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	$	1		$	4

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			Total
(millions)
Three Months Ended March 31, 2012
Total gains (losses) included in earnings	$	(9	)	$	(26	)	$	(35	)
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		1			—			1
Three Months Ended March 31, 2011
Total gains (losses) included in earnings	$	(2	)	$	16		$	14
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

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)
At March 31, 2012
Assets:
Derivatives:
Commodity	$	—	$	—	$	1	$	1
Investments(1):
Equity securities:
U.S.:
Large cap		764		—		—		764
Other		27		—		—		27
Fixed income:
Corporate debt instruments		—		197		—		197
U.S. Treasury securities and agency debentures		123		65		—		188
State and municipal		—		129		—		129
Other		—		13		—		13
Cash equivalents and other		—		41		—		41
Restricted cash equivalents		—		29		—		29
Total assets	$	914	$	474	$	1	$	1,389
Liabilities:
Derivatives:
Commodity	$	—	$	21	$	18	$	39
Interest rate		—		38		—		38
Total liabilities	$	—	$	59	$	18	$	77
At December 31, 2011
Assets:
Derivatives:
Commodity	$	—	$	—	$	2	$	2
Investments(1):
Equity securities:
U.S.:
Large cap		679		—		—		679
Other		23		—		—		23
Fixed income:
Corporate debt instruments		—		214		—		214
U.S. Treasury securities and agency debentures		107		63		—		170
State and municipal		—		125		—		125
Other		—		16		—		16
Cash equivalents and other		—		40		—		40
Restricted cash equivalents		—		32		—		32
Total assets	$	809	$	490	$	2	$	1,301
Liabilities:
Derivatives:
Commodity	$	—	$	17	$	30	$	47
Interest rate		—		100		—		100
Total liabilities	$	—	$	117	$	30	$	147

(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 March 31,
	2012			2011
(millions)
Beginning balance	$	(28	)	$	14
Total realized and unrealized gains (losses):
Included in earnings		(27	)		16
Included in regulatory assets/liabilities		11			(21	)
Settlements		27			(16	)
Ending balance	$	(17	)	$	(7	)

The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases in Virginia Power’s Consolidated Statements of Income for the three months ended March 31, 2012 and 2011. 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 months ended March 31, 2012 and 2011.

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:

	March 31, 2012				December 31, 2011
	Carrying Amount		Estimated  Fair Value(1)		Carrying Amount		Estimated  Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	16,695	$	19,256	$	16,264	$	18,936
Long-term debt, VIE(3)		882		889		890		892
Junior subordinated notes payable to affiliates		268		272		268		268
Enhanced junior subordinated notes		1,365		1,437		1,451		1,518
Subsidiary preferred stock(4)		257		259		257		256
Virginia Power
Long-term debt, including securities due within one year(2)	$	7,308	$	8,628	$	6,862	$	8,281
Preferred stock(4)		257		259		257		256

(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. All fair value measurements are classified as Level 2. 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 March 31, 2012 and December 31, 2011, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $93 million and $105 million, respectively.

(3) Includes amounts which represent the unamortized premium.

(4) Includes deferred issuance expenses of $2 million at March 31, 2012 and December 31, 2011.

PAGE 24

Note 7. 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, 2011. See Note 6 in this report for further information about fair value measurements and associated valuation methods for derivatives.

Dominion

The following table presents the volume of Dominion’s derivative activity as of March 31, 2012. 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 transactions, 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)		315		74
Basis(1)		861		484
Electricity (MWh):
Fixed price(1)		21,953,642		21,718,420
FTRs		21,805,241		810,816
Capacity (MW)		63,825		272,968
Liquids (gallons)(2)		137,508,000		221,214,000
Interest rate	$	2,000,000,000	$	1,940,000,000

(1) Includes options.

(2) Includes NGLs and oil.

For the three months ended March 31, 2012, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness 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.

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion’s Consolidated Balance Sheet at March 31, 2012:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings during the next  12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	(30	)	$	(16	)		33 months
Electricity		243			102			45 months
NGLs		(64	)		(27	)		33 months
Other		6			2			38 months
Interest rate		(97	)		(12	)		369 months
Total	$	58		$	49

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 and interest rates.

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)
March 31, 2012
ASSETS
Current Assets
Commodity	$	312	$	472	$	784
Interest rate		38		—		38
Total current derivative assets		350		472		822
Noncurrent Assets
Commodity		295		99		394
Interest rate		56		—		56
Total noncurrent derivative assets(1)		351		99		450
Total derivative assets	$	701	$	571	$	1,272
LIABILITIES
Current Liabilities
Commodity	$	206	$	492	$	698
Interest rate		158		15		173
Total current derivative liabilities		364		507		871
Noncurrent Liabilities
Commodity		151		85		236
Interest rate		—		3		3
Total noncurrent derivative liabilities(2)		151		88		239
Total derivative liabilities	$	515	$	595	$	1,110
December 31, 2011
ASSETS
Current Assets
Commodity	$	176	$	495	$	671
Interest rate		34		—		34
Total current derivative assets		210		495		705
Noncurrent Assets
Commodity		198		96		294
Interest rate		71		—		71
Total noncurrent derivative assets(1)		269		96		365
Total derivative assets	$	479	$	591	$	1,070
LIABILITIES
Current Liabilities
Commodity	$	162	$	530	$	692
Interest rate		222		37		259
Total current derivative liabilities		384		567		951
Noncurrent Liabilities
Commodity		118		78		196
Interest rate		—		10		10
Total noncurrent derivative liabilities(2)		118		88		206
Total derivative liabilities	$	502	$	655	$	1,157

(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

The following tables present the gains and losses on Dominion’s derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:

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 March 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	64
Purchased gas					(30	)
Electric fuel and other energy-related purchases					(7	)
Total commodity	$	176			27		$	(1	)
Interest rate(3)		32			1			27
Total	$	208		$	28		$	26
Three Months Ended March 31, 2011
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	28
Purchased gas					(48	)
Electric fuel and other energy-related purchases					1
Purchased electric capacity					1
Total commodity	$	(142	)		(18	)	$	(5	)
Interest rate(3)		(1	)		—			(1	)
Total	$	(143	)	$	(18	)	$	(6	)

(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.

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended March 31,
Derivatives not designated as hedging instruments	2012			2011
(millions)
Derivative Type and Location of Gains (Losses)
Commodity
Operating revenue	$	69		$	19
Purchased gas		(10	)		(11	)
Electric fuel and other energy-related purchases		(27	)		16
Interest rate(2)		(2	)		—
Total	$	30		$	24

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

PAGE 27

Virginia Power

The following table presents the volume of Virginia Power’s derivative activity as of March 31, 2012. 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 transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price		21		—
Basis		10		—
Electricity (MWh):
Fixed price		664,000		—
FTRs		20,365,031		195,840
Capacity (MW)		30,500		182,500
Interest rate	$	750,000,000	$	90,000,000

For the three months ended March 31, 2012 and 2011, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness 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.

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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)
March 31, 2012
ASSETS
Current Assets
Commodity	$	—	$	1	$	1
Total current derivative assets(1)		—		1		1
Total derivative assets	$	—	$	1	$	1
LIABILITIES
Current Liabilities
Commodity	$	17	$	20	$	37
Interest rate		20		15		35
Total current derivative liabilities(2)		37		35		72
Noncurrent Liabilities
Commodity		2		—		2
Interest rate		—		3		3
Total noncurrent derivative liabilities(3)		2		3		5
Total derivative liabilities	$	39	$	38	$	77
December 31, 2011
ASSETS
Current Assets
Commodity	$	—	$	2	$	2
Total current derivative assets(1)		—		2		2
Total derivative assets	$	—	$	2	$	2
LIABILITIES
Current Liabilities
Commodity	$	14	$	31	$	45
Interest rate		53		37		90
Total current derivative liabilities(2)		67		68		135
Noncurrent Liabilities
Commodity		2		—		2
Interest rate		—		10		10
Total noncurrent derivative liabilities(3)		2		10		12
Total derivative liabilities	$	69	$	78	$	147

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

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

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

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The following tables present the gains and losses on Virginia Power’s derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:

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 March 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(2	)
Total commodity	$	(2	)		(2	)	$	(1	)
Interest rate(3)		1			—			27
Total	$	(1	)	$	(2	)	$	26
Three Months Ended March 31, 2011
Derivative Type and Location of Gains (Losses)
Commodity:
Purchased electric capacity				$	1
Total commodity	$	—			1		$	(5	)
Interest rate(3)		—			—			(1	)
Total	$	—		$	1		$	(6	)

(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.

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended March 31,
Derivatives not designated as hedging instruments	2012			2011
(millions)
Derivative Type and Location of Gains (Losses)
Commodity(2)	$	(27	)	$	16
Interest rate(3)		(2	)		—
Total	$	(29	)	$	16

(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.

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Note 8. Investments

Dominion

Equity and Debt Securities

Rabbi Trust Securities

Marketable equity and debt securities and cash equivalents held in Dominion’s rabbi trusts and classified as trading totaled $95 million and $90 million at March 31, 2012 and December 31, 2011, respectively. Net unrealized gains on trading securities totaled $4 million and $3 million for the three months ended March 31, 2012 and 2011, respectively. Cost method investments held in Dominion’s rabbi trusts totaled $16 million and $17 million at March 31, 2012 and December 31, 2011, respectively.

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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 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)
March 31, 2012
Marketable equity securities
U.S.:
Large Cap	$	1,178	$	724	$	—		$	1,902
Other		38		15		—			53
Marketable debt securities:
Corporate bonds		296		22		(1	)		317
U.S. Treasury securities and agency debentures		459		18		(1	)		476
State and municipal		267		21		—			288
Other		19		1		—			20
Cost method investments		117		—		—			117
Cash equivalents and other(2)		58		—		—			58
Total	$	2,432	$	801	$	(2	)(3)	$	3,231
December 31, 2011
Marketable equity securities:
U.S.:
Large Cap	$	1,152	$	537	$	—		$	1,689
Other		36		10		—			46
Marketable debt securities:
Corporate bonds		314		19		(1	)		332
U.S. Treasury securities and agency debentures		437		20		(1	)		456
State and municipal		264		24		—			288
Other		23		1		—			24
Cost method investments		118		—		—			118
Cash equivalents and other(2)		46		—		—			46
Total	$	2,390	$	611	$	(2	)(3)	$	2,999

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

(2) Includes pending purchases of securities of $20 million and $11 million at March 31, 2012 and December 31, 2011, respectively.

(3) The fair value of securities in an unrealized loss position was $192 million and $164 million at March 31, 2012 and December 31, 2011, respectively.

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The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at March 31, 2012 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	62
Due after one year through five years		324
Due after five years through ten years		338
Due after ten years		377
Total	$	1,101

Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended March 31,
	2012		2011
(millions)
Proceeds from sales	$	415	$	502
Realized gains(1)		28		14
Realized losses(1)		4		8

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

Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds for Dominion were not material for the three months ended March 31, 2012 and 2011.

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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 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)
March 31, 2012
Marketable equity securities:
U.S.:
Large Cap	$	469	$	294	$	—		$	763
Other		19		8		—			27
Marketable debt securities:
Corporate bonds		185		13		(1	)		197
U.S. Treasury securities and agency debentures		185		4		(1	)		188
State and municipal		121		8		—			129
Other		12		1		—			13
Cost method investments		117		—		—			117
Cash equivalents and other(2)		33		—		—			33
Total	$	1,141	$	328	$	(2	)(3)	$	1,467
December 31, 2011
Marketable equity securities
U.S.:
Large Cap	$	460	$	218	$	—		$	678
Other		18		5		—			23
Marketable debt securities:
Corporate bonds		204		11		(1	)		214
U.S. Treasury securities and agency debentures		166		4		—			170
State and municipal		114		10		—			124
Other		16		1		(1	)		16
Cost method investments		118		—		—			118
Cash equivalents and other(2)		27		—		—			27
Total	$	1,123	$	249	$	(2	)(3)	$	1,370

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

(2) Includes pending purchases of securities of $8 million and $13 million at March 31, 2012 and December 31, 2011, respectively.

(3) The fair value of securities in an unrealized loss position was $115 million and $99 million at March 31, 2012 and December 31, 2011, respectively.

The fair value of Virginia Power’s debt securities at March 31, 2012 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	2
Due after one year through five years		162
Due after five years through ten years		199
Due after ten years		164
Total	$	527

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

	Three Months Ended March 31,
	2012		2011
(millions)
Proceeds from sales	$	191	$	343
Realized gains(1)		11		5
Realized losses(1)		2		4

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

Other-than-temporary impairment losses on investments for Virginia Power were not material for the three months ended March 31, 2012 and 2011.

Note 9. Regulatory Matters

Regulatory Matters Involving Potential Loss Contingencies

As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. This estimated range is based on currently available information and involves elements of judgment and significant uncertainties. This estimated range of possible loss does not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on Dominion’s or Virginia Power’s financial position, liquidity or results of operations.

FERC - Electric

Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public utilities. Virginia Power purchases and sells electricity in the PJM wholesale market and Dominion’s merchant generators sell electricity in the PJM, MISO and ISO-NE wholesale markets under Dominion’s market-based sales tariffs authorized by FERC. In addition, Virginia Power has FERC approval of a tariff to sell wholesale power at capped rates based on its embedded cost of generation. This cost-based sales tariff could be used to sell to loads within or outside Virginia Power’s service territory. Any such sales would be voluntary.

Rates

In April 2008, FERC granted an application for Virginia Power’s electric transmission operations to establish a forward-looking formula rate mechanism that updates transmission rates on an annual basis and approved an ROE of 11.4%, effective as of January 1, 2008. The formula rate is designed to recover the expected revenue requirement for each calendar year and is updated based on actual costs. The FERC-approved formula method, which is based on projected costs, allows Virginia Power to earn a current return on its growing investment in electric transmission infrastructure.

In July 2008, Virginia Power filed an application with FERC requesting a revision to its revenue requirement to reflect an additional ROE incentive adder for eleven electric transmission enhancement projects. Under the proposal, the cost of transmission service would increase to include an ROE incentive adder for each of the eleven projects, beginning the date each project enters commercial operation (but not before January 1, 2009). Virginia Power proposed an incentive of 1.5% for four of the projects and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008. All eleven projects are currently expected to be completed by the end of 2012. Numerous parties sought rehearing of the FERC order in August 2008, and rehearing is pending. Although Virginia Power cannot predict the outcome of the rehearing, it is not expected to have a material effect on results of operations.

In March 2010, ODEC and NCEMC filed a complaint with FERC against Virginia Power 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

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remaining part of the complaint. In February 2012, Virginia Power submitted to FERC a settlement agreement to resolve all issues set for hearing. All transmission customer parties to the proceeding joined the settlement. The Virginia Commission, North Carolina Commission and Public Staff of the North Carolina Commission, while not parties to the settlement, have agreed to not oppose the settlement. If accepted by FERC, the settlement provides for payment by Virginia Power to the transmission customer parties collectively of $250,000 per year for ten years and resolves all matters other than the incremental cost of certain underground transmission facilities, which will be set for briefing. While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations.

PJM

In November 2011, PJM issued a formal notification that it would recalculate certain ancillary service revenues that had previously been paid during 2009, 2010 and 2011. Also in November 2011, PJM requested FERC permission to suspend its rebilling and repayment obligations associated with the recalculation of such revenues and petitioned FERC to establish a proceeding to determine the appropriate recalculations for the revenues during this period. In December 2011, FERC permitted the suspension of rebilling and repayment by PJM, subject to the outcome of FERC’s proceedings to determine the appropriate revenue recalculation. In April 2012, FERC issued an Order Establishing Hearing and Settlement Judge Procedures to address the appropriate recalculation of the ancillary service credits PJM will be required to collect from Virginia Power. Virginia Power has accrued a liability of $36 million as of March 31, 2012 for estimated future billing adjustments from PJM related to the ancillary service revenues.

Other 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, 2011.

Virginia Regulation

Biennial Review

In November 2011, the Virginia Commission issued the Biennial Review Order, which included a determination that Virginia Power’s new authorized ROE is 10.9%, inclusive of a performance incentive of 50 basis points for meeting certain RPS targets. In December 2011, Virginia Power filed a petition with the Virginia Commission seeking rehearing or reconsideration of the Biennial Review Order, to confirm the effective date of the newly authorized 10.9% base ROE. Virginia Power’s petition requested the Virginia Commission to confirm that the 10.9% ROE authorized in the Biennial Review Order would apply prospectively, effective following the date of the Biennial Review Order on November 30, 2011, and that Virginia Power’s previously-approved 11.9% base ROE authorized in the Virginia Settlement Approval Order would be used to measure base rate earnings for the period January 1, 2011 through November 30, 2011. In March 2012, the Virginia Commission issued an order denying Virginia Power’s petition seeking rehearing or reconsideration. Contrary to Virginia Power’s position, the Virginia Commission ruled that the new 10.9% ROE will be used to measure earnings for the entire 2011-2012 test period in the next biennial review in 2013. Also in March 2012, Virginia Power filed Petitions for Appeal with the Supreme Court of Virginia regarding the Biennial Review Order and the March 2012 order.

In the Biennial Review Order, the Virginia Commission declined to award a performance incentive for generating plant performance, customer service or operating efficiency in connection with the 2009-2010 biennial review. Instead, in March 2012, the Virginia Commission issued an order initiating a rulemaking proceeding to develop specific performance metrics and nationally recognized standards for determining positive or negative performance incentives for electric utilities. Such incentive criteria would be applied in future biennial review proceedings. Virginia Power expects the Staff of the Virginia Commission to file proposed rules and regulations for performance incentives in September 2012.

Generation Riders R and S

In March 2012, the Virginia Commission approved annual updates for Riders R and S for the April 1, 2012 to March 31, 2013 rate year, utilizing an 11.4% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The Virginia Commission’s approvals authorized an approximately $74 million revenue requirement for Rider R, and an approximately $226 million revenue requirement for Rider S, comprised of approximately $52 million for the pre-commercial operation period and approximately $174 million for the commercial operation period.

Generation Rider B

In March 2012, the Virginia Commission approved the conversion of the Altavista, Hopewell, and Southampton power stations to biomass. The conversions will increase Dominion’s renewable generation by more than 150 MW. The conversions are expected to be completed by the end of 2013.

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As part of its approval, the Virginia Commission also approved Rider B. The approved revenue requirement for Rider B is approximately $6 million for the April 1, 2012 to March 31, 2013 rate year, utilizing a 12.4% ROE (inclusive of a 200 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The renewable generating unit statutory enhancement of 200 basis points will apply during construction and the first five years of the service lives of the converted facilities.

North Carolina Regulation

In March 2012, Virginia Power filed an application with the North Carolina Commission to increase base non-fuel revenues by approximately $64 million, with January 1, 2013 as the proposed effective date for the permanent rate revision. Virginia Power plans to file an application in August 2012 to decrease its fuel rates. The net effect of the proposed change in base rates and current estimate of fuel charges would be a net revenue increase of approximately $37 million. Virginia Power intends to implement rates on a temporary basis, subject to refund, on November 1, 2012, as permitted by North Carolina law. Virginia Power expects to receive an order from the North Carolina Commission in December 2012.

Ohio Regulation

In February 2012, East Ohio submitted an application with the Ohio Commission to adjust the cost recovery charge for costs associated with PIR investments for the six months ended December 31, 2011. The filing was made in accordance with changes to the PIR program approved by the Ohio Commission in August 2011 and effects a transition from a fiscal year ending June 30 to a calendar year for annual filings thereafter. The application includes total gross plant investment for the six-month July 1-December 31, 2011 transition period of $73 million, cumulative gross plant investment of $362 million, and a revenue requirement of $47 million. A stipulation was submitted by East Ohio, the Staff of the Ohio Commission and the Ohio Consumers’ Counsel that supports the rates filed by East Ohio. The Ohio Commission issued an order approving the stipulation in April 2012.

FERC Gas - Cove Point Rate Case

In May 2011, Cove Point filed a general rate case for its FERC-jurisdictional services, with proposed rates to be effective July 1, 2011. In June 2011, FERC accepted a July 1, 2011 effective date for all proposed rates but two, for which the effective date was suspended from July 1 to December 1, 2011. In December 2011, Cove Point, FERC trial staff and the other active parties in the rate case reached a settlement in principle on all issues set for hearing by FERC, as well as on all outstanding proposed tariff changes filed in May 2011. In April 2012, Cove Point filed a stipulation and agreement resolving all outstanding issues in the rate case and establishing the mechanism for operational purchases of LNG. The settlement is subject to FERC approval. Settlement rates and tariff changes will be effective retroactive to April 1, 2012, once the FERC order approving the settlement is no longer subject to rehearing or appeal. Cove Point and settling customers will be subject to a rate moratorium through December 31, 2016. Cove Point is required to file its next rate case with rates to be effective January 1, 2017.

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Note 10. 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, 2011, 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 summer generation capacity of approximately 870 MW. 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 entities 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 $1.2 billion as of March 31, 2012. Virginia Power paid $55 million and $53 million for electric capacity and $19 million and $39 million for electric energy to these entities in the three months ended March 31, 2012 and 2011, respectively.

Virginia Power purchased shared services from DRS, an affiliated VIE, of approximately $96 million and $93 million for the three months ended March 31, 2012 and 2011, 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.

See 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, 2011 for additional information about consolidated VIEs.

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Note 11. Significant Financing Transactions

Credit Facilities and Short-term Debt

Dominion and Virginia Power use short-term debt to fund working capital requirements and as a bridge to long-term debt financings. 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. Collateral requirements are impacted by commodity prices, hedging levels, Dominion’s credit ratings and the credit quality of its counterparties.

At March 31, 2012, Dominion’s commercial paper and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:

	Facility Limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	3,000	$	1,057	$	—	$	1,943
Joint revolving credit facility(2)		500		—		36		464
Total	$	3,500	$	1,057	$	36	$	2,407

(1) This credit facility has a maturity date of September 2016, and 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.

(2) This credit facility has a maturity date of September 2016, and can be used to support bank borrowings, commercial paper and letter of credit issuances.

Virginia Power’s short-term financing is supported by two joint revolving credit facilities with Dominion. These credit facilities are being used for working capital, as support for the combined commercial paper programs of Dominion and Virginia Power and for other general corporate purposes.

At March 31, 2012, Virginia Power’s share of commercial paper and letters of credit outstanding, as well as its capacity available under its joint credit facilities with Dominion were as follows:

	Facility Sub-limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	1,000	$	255	$	—	$	745
Joint revolving credit facility(2)		250		—		15		235
Total	$	1,250	$	255	$	15	$	980

(1) This credit facility has a maturity date of September 2016, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (or the sub-limit, whichever is less) of letters of credit. Virginia Power’s current sub-limit under this credit facility can be increased or decreased multiple times per year.

(2) This credit facility has a maturity date of September 2016, and can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power’s current sub-limit under this credit facility can be increased or decreased multiple times per year.

In addition to the credit facility commitments mentioned above, Virginia Power also has a $120 million credit facility with a maturity date of September 2016. This facility supports certain tax-exempt financings of Virginia Power.

Long-term Debt

In January 2012, Virginia Power issued $450 million of 2.95% senior notes that mature in 2022.

Convertible Securities

At March 31, 2012, Dominion had $137 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 March 31, 2012, the conversion rate has been adjusted, primarily due to individual dividend payments above the level paid at issuance, to 29.0360 shares of common stock per $1,000 principal amount of senior notes, which represents a conversion price of $34.44.

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The senior notes are eligible for conversion during any calendar quarter when the closing price of Dominion’s common stock was equal to or higher than 120% of the conversion price for at least 20 out of the last 30 consecutive trading days of the preceding quarter. During the three months ended March 31, 2012, the senior notes were eligible for conversion and approximately $6 million of the notes were converted by holders. The senior notes are eligible for conversion during the second quarter of 2012.

Enhanced Junior Subordinated Notes

In February 2012, Dominion launched a tender offer to purchase up to $150 million of the September 2006 hybrids, which amount could be increased or decreased at Dominion’s sole discretion. In the first quarter of 2012, Dominion purchased and canceled approximately $86 million of the September 2006 hybrids primarily as a result of this tender offer, which expired on March 23, 2012. All purchases were conducted in compliance with the RCC. From time to time, Dominion may reduce its outstanding debt and level of interest expense through redemption of debt securities prior to maturity and repurchases in the open market, in privately negotiated transactions, through additional tender offers or otherwise.

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Note 12. Commitments and Contingencies

As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, and/or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. This estimated range is based on currently available information and involves elements of judgment and significant uncertainties. This estimated range of possible loss does not represent the Companies’ maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on Dominion’s or Virginia Power’s financial position, liquidity or results of operations.

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.

Air

The CAA is a comprehensive program utilizing a broad range of regulatory tools to protect and preserve the nation’s air quality. At a minimum, states are required to establish regulatory programs to address all requirements of the CAA. However, states may choose to develop regulatory programs that are more restrictive. Many of Dominion’s and Virginia Power’s facilities are subject to the CAA’s permitting and other requirements.

On December 21, 2011, the EPA issued MATS for coal and oil-fired electric utility steam generating units. The rule establishes strict emission limits for mercury, particulate matter as a surrogate for toxic metals and hydrogen chloride as a surrogate for acid gases. The rule includes a limited use provision for oil-fired units with annual capacity factors under 8% that provides an exemption from emission limits, and allows compliance with operational work practice standards. Compliance will be required by Spring 2015, with certain limited exceptions. Other than impacts disclosed in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2011, the cost to comply with the rule is not expected to be material. Dominion continues to be governed by individual state mercury emission reduction regulations in Massachusetts and Illinois that are largely unaffected by this rule.

In July 2011, the EPA issued a final replacement rule for CAIR, called CSAPR, that requires 28 states to reduce power plant emissions that cross state lines. CSAPR establishes new SO₂ and NO_x emissions cap and trade programs that are completely independent of the current ARP. Specifically, CSAPR requires reductions in SO₂ and NO_x emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NO_x emissions caps, NO_x emissions caps during the ozone season (May 1 through September 30) and annual SO₂ emission caps with differing requirements for two groups of affected states.

With respect to Dominion’s generation fleet, the cost to comply with the rule is not expected to be material. However, following numerous petitions by industry participants for review and motions for stay, the U.S. Court of Appeals for the D.C. Circuit issued a ruling in December 2011 to stay CSAPR pending judicial review. Also, in the fourth quarter of 2011, the EPA proposed technical revisions to CSAPR. Accordingly, future outcomes of litigation and/or final action to modify the rule could affect this assessment. While the stay of CSAPR is in effect, the EPA will continue to administer CAIR.

In February 2008, Dominion received a request for information pursuant to Section 114 of the CAA from the EPA. The request concerns historical operating changes and capital improvements undertaken at State Line and Kincaid. In April 2009, Dominion received a second request for information. Dominion provided information in response to both requests. Also in April 2009, Dominion received a Notice and Finding of Violations from the EPA claiming violations of the CAA New Source Review requirements, NSPS, the Title V permit program and the stations’ respective State Implementation Plans. The Notice states that the EPA may issue an order requiring compliance with the relevant CAA provisions and may seek injunctive relief and/or civil penalties, all pursuant to the EPA’s enforcement authority under the CAA.

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Dominion believes that it complied with applicable laws and the EPA regulations and interpretations in effect at the time the work in question took place. The CAA authorizes maximum civil penalties of $25,000 to $37,500 per day, per violation at each generating unit, depending on the date of the alleged violation. In addition to any such penalties that may be awarded, an adverse outcome could require substantial capital expenditures or affect the timing of currently budgeted capital expenditures. Such expenditures could affect future results of operations, cash flows, and financial condition. Dominion is currently unable to make an estimate of the potential financial statement impacts related to these matters.

Water

The CWA is a comprehensive program requiring a broad range of regulatory tools including a permit program to authorize and regulate discharges to surface waters with strong enforcement mechanisms. Dominion and Virginia Power must comply with all aspects of the CWA programs at their operating facilities.

In October 2003, the EPA and the Massachusetts Department of Environmental Protection each issued new NPDES permits for Brayton Point. The new permits contained identical conditions that in effect require the installation of cooling towers to address concerns over the withdrawal and discharge of cooling water. Currently, Dominion is constructing the cooling towers and estimates the total cost to install these cooling towers at approximately $570 million, with remaining expenditures of approximately $65 million included in its planned capital expenditures through 2012.

In September 2010, Millstone’s NPDES permit was reissued under the CWA. 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. Dominion is currently unable to make an estimate of the potential financial statement impacts related to this matter.

Solid and Hazardous Waste

The CERCLA, as amended, provides for immediate response and removal actions coordinated by the EPA in the event of threatened releases of hazardous substances into the environment and authorizes the U.S. government either to clean up sites at which hazardous substances have created actual or potential environmental hazards or to order persons responsible for the situation to do so. Under the CERCLA, as amended, generators and transporters of hazardous substances, as well as past and present owners and operators of contaminated sites, can be strictly, jointly and severally liable for the cost of cleanup. These potentially responsible parties can be ordered to perform a cleanup, be sued for costs associated with an EPA-directed cleanup, voluntarily settle with the U.S. government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight.

From time to time, Dominion or Virginia Power may be identified as a potentially responsible party to a Superfund site. The EPA (or a state) can either allow such a party to conduct and pay for a remedial investigation, feasibility study and remedial action or conduct the remedial investigation and action itself and then seek reimbursement from the potentially responsible parties. Each party can be held jointly, severally and strictly liable for the cleanup costs. These parties can also bring contribution actions against each other and seek reimbursement from their insurance companies. As a result, Dominion or Virginia Power may be responsible for the costs of remedial investigation and actions under the Superfund law or other laws or regulations regarding the remediation of waste. Except as noted below, the Companies do not believe this will have a material effect on results of operations, financial condition and/or cash flows.

In September 2011, the EPA issued a UAO to Virginia Power and 22 other parties, ordering specific remedial action of certain areas at the Ward Transformer Superfund site located in Raleigh, North Carolina. Virginia Power does not believe it is a liable party under CERCLA based on its alleged connection to the site. In November 2011, Virginia Power and a number of other parties notified the EPA that they are declining to undertake the work set forth in the UAO.

The EPA may seek to enforce a UAO in court pursuant to its enforcement authority under CERCLA, and may seek recovery of its costs in undertaking removal or remedial action. If the court determines that a respondent failed to comply with the UAO without sufficient cause, the EPA may also seek civil penalties of up to $37,500 per day for the violation and punitive damages of up to three times the costs incurred by the EPA as a result of the party’s failure to comply with the UAO. Virginia Power is currently unable to make an estimate of the potential financial statement impacts related to the Ward Transformer matter.

Dominion has determined that it is associated with 17 former manufactured gas plant sites. Studies conducted by other utilities at their former manufactured gas plant sites have indicated that those sites contain coal tar and other potentially harmful materials. None of the 17 former sites with which Dominion is associated is under investigation by any state or federal environmental agency. At one of the former sites, Dominion is conducting a state-approved post closure groundwater monitoring program and an environmental land use restriction has been recorded. Another site has been accepted into a state-based voluntary remediation program and Dominion has not yet estimated the future remediation costs. Due to the uncertainty surrounding these sites, Dominion is unable to make an estimate of the potential financial statement impacts related to these sites.

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Climate Change Legislation and Regulation

Massachusetts, Rhode Island and Connecticut, among other states, have joined RGGI, a multi-state effort to reduce CO₂ emissions in the Northeast implemented through state specific regulations. Under the initiative, aggregate CO₂ emissions from power plants in participating states are required to be stabilized at current levels from 2009 to 2015. Further reductions from current levels would be required to be phased in starting in 2016 such that by 2019 there would be a 10% reduction in participating state power plant CO₂ emissions. During 2012, RGGI will undergo a program review which could impact regulations and implementation of RGGI. The impact of this program review on Dominion’s fossil fired generation operations in RGGI states is unknown at this time, and Dominion is currently unable to make an estimate of the potential financial statement impacts related to these matters.

Three of Dominion’s facilities, Brayton Point, Salem Harbor and Manchester Street, are subject to RGGI. Beginning with calendar year 2009, RGGI requires that Dominion cover each ton of CO₂ direct stack emissions from these facilities with either an allowance or an offset. The allowances can be purchased through auction or through a secondary market. Dominion has periodically participated in RGGI allowance auctions to date and has procured allowances to meet its estimated compliance requirements under RGGI’s current requirement for 2009 through 2014 and partially for 2015, therefore Dominion does not expect compliance with RGGI to have a material impact on its results of operations or financial condition. During June 2011, a lawsuit was filed in New York seeking to retroactively rescind RGGI participation by that state. A percentage of Dominion’s RGGI allowances had been acquired from New York. The allocated value of these allowances totaled approximately $38 million, of which all have been expensed as consumed for RGGI Phase I compliance. In February 2012, Dominion surrendered these New York RGGI allowances for the RGGI Phase I compliance period and therefore does not expect any significant financial statement impacts from this lawsuit as it no longer holds allowances issued by the state of New York.

MF Global

Prior to October 31, 2011, certain of Dominion’s subsidiaries executed certain commodity transactions on exchanges using MF Global, an FCM registered with the CFTC. In order to secure its potential exposure on these commodity transactions, Dominion posted certain required margin collateral with MF Global. The parent company of MF Global, MF Global Holdings Ltd., filed for bankruptcy relief under Chapter 11 of the U.S. Bankruptcy Code on October 31, 2011. On the same date, the U.S. District Court for the Southern District of New York appointed a trustee to oversee the liquidation of MF Global pursuant to the Securities Investor Protection Act.

In accordance with court-approved procedures, Dominion transferred to other FCMs all open positions executed using MF Global. The initial margin posted for these open positions at October 31, 2011 was approximately $73 million. Dominion has received approximately $8 million of this amount through the liquidation process to date.

At this time, the MF Global trustee is determining the final amounts that will be recoverable and ultimately distributed to MF Global’s customers. As part of this process, the trustee has filed claims in the insolvency proceeding of MF Global affiliates in various foreign jurisdictions, including the United Kingdom, which claims are still pending. Due to the uncertainty surrounding the ultimate recovery on the claims filed by the MF Global trustee in the United Kingdom and elsewhere, the uncertain timing of such recovery, and the potential dilution of such recovered funds in the liquidation process, Dominion is unable to estimate the loss, if any, associated with its remaining margin claims or when it will receive any additional recoveries on such claims.

Nuclear Matters

In March 2011, a magnitude 9.0 earthquake and subsequent tsunami caused significant damage at the Fukushima Daiichi nuclear power station in northeast Japan. These events have resulted in significant nuclear safety reviews required by the NRC and industry groups such as INPO. Like other U.S. nuclear operators, Dominion has been gathering supporting data and participating in industry initiatives focused on the ability to respond to and mitigate the consequences of design-basis and beyond-design-basis events at its stations.

In March 2012, the NRC issued orders and information requests requiring specific reviews and actions to all operating reactors, construction permit holders and combined license holders based on the lessons learned from the Fukushima Daiichi event. The orders applicable to Dominion require implementation of safety enhancements related to mitigation strategies to respond to extreme natural events resulting in the loss of power at plants, and enhancing spent fuel pool instrumentation. The orders require prompt implementation of the safety enhancements and completion of implementation within two refueling outages or by December 31, 2016, whichever comes first. Information requests issued by the NRC request each reactor to reevaluate the seismic and flooding hazards at their site using present-day methods and information, conduct walkdowns of their facilities to ensure protection against the hazards in their current design basis, and to reevaluate their emergency communications systems and staffing levels. These orders could require U.S. nuclear facilities, including those owned by Dominion and Virginia Power,

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to undertake plant modifications or perform additional analyses that may result in increased costs and capital requirements. Dominion and Virginia Power are evaluating the orders and information requests issued by the NRC and are currently unable to estimate the potential financial impacts related to these matters.

Guarantees

Dominion

At March 31, 2012, Dominion had issued $77 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of March 31, 2012, Dominion’s exposure under these guarantees was $45 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 its 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.

At March 31, 2012, Dominion had issued the following subsidiary guarantees:

	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	363	$	363
Commodity transactions(3)		3,360		273
Nuclear obligations(4)		231		62
Other(5)		481		44
Total	$	4,435	$	742

(1) Represents the estimated portion of the guarantee’s stated limit that is utilized as of March 31, 2012 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, including subsidiaries of Virginia Power and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and 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 limits.

(4) 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.

(5) 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.

Surety Bonds and Letters of Credit

As of March 31, 2012, Dominion had purchased $155 million of surety bonds, including $62 million at Virginia Power, and authorized the issuance of standby letters of credit by financial institutions of $36 million, including $15 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.

Merchant Generation Operations

Dominion continually reviews its portfolio of assets to determine which assets fit strategically and support its objectives to improve return on invested capital and shareholder value. If Dominion identifies assets that do not support its objectives, it may consider such assets for divestiture. In connection with this effort, in the first quarter of 2011, Dominion decided to pursue the sale of Kewaunee. If these efforts are successful, Dominion may be required to present Kewaunee’s assets and liabilities that are subject to sale as held for sale in its Consolidated Balance Sheet and Kewaunee’s results of operations in discontinued

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operations in its Consolidated Statements of Income. Held for sale classification would require that amounts be recorded at the lower of book value or sale price less costs to sell and could result in the recording of an impairment charge. Any sale of Kewaunee would be subject to the approval of Dominion’s Board of Directors, as well as applicable state and federal approvals.

Note 13. Credit Risk

Dominion’s and Virginia Power’s accounting policies for credit risk are discussed in Note 24 to the Consolidated Financial Statements in their Annual Report on Form 10-K for the year ended December 31, 2011.

At March 31, 2012, Dominion’s gross credit exposure totaled $531 million. After the application of collateral, credit exposure was reduced to $461 million. Of this amount, investment grade counterparties, including those internally rated, represented 81%. One counterparty exposure represented 11% of Dominion’s total exposure and is a large financial institution rated investment grade. At March 31, 2012, Virginia Power’s exposure to potential concentrations of credit risk was not considered material.

Credit-Related Contingent Provisions

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 rating 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 March 31, 2012 and December 31, 2011, Dominion would have been required to post an additional $71 million and $88 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 $145 million in collateral, including $4 million of letters of credit, at March 31, 2012 and $110 million in collateral, including $4 million of letters of credit, at December 31, 2011, 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 March 31, 2012 and December 31, 2011 was $277 million and $259 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power were not material as of March 31, 2012 and December 31, 2011. See Note 7 for further information about derivative instruments.

Note 14. 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 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 risk associated with purchases of natural gas.

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

Presented below are significant transactions with DRS and other affiliates:

	Three Months Ended March 31,
	2012		2011
(millions)
Commodity purchases from affiliates	$	78	$	62
Services provided by affiliates		96		93

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 $187 million as of both March 31, 2012 and December 31, 2011. There were no short-term demand note borrowings from Dominion as of March 31, 2012 and December 31, 2011. Interest charges related to Virginia Power’s borrowings from Dominion were immaterial for the three months ended March 31, 2012 and 2011, respectively.

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Note 15. Employee Benefit Plans

The components of Dominion’s provision for net periodic benefit cost were as follows:

	Pension Benefits						Other Postretirement Benefits
	2012			2011			2012			2011
(millions)
Three Months Ended March 31,
Service cost	$	29		$	27		$	11		$	12
Interest cost		67			64			20			23
Expected return on plan assets		(108	)		(110	)		(21	)		(20	)
Amortization of prior service cost (credit)		1			1			(3	)		(3	)
Amortization of net loss		33			24			2			3
Net periodic benefit cost	$	22		$	6		$	9		$	15

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Employer Contributions

During the three months ended March 31, 2012, Dominion made no contributions to its defined benefit pension plans or OPEB plans. Dominion expects to contribute approximately $16 million to its OPEB plans through Voluntary Employees’ Beneficiary Associations during the remainder of 2012.

Note 16. 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 and storage	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.

In the three months ended March 31, 2012, Dominion reported an after-tax net benefit of $7 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments. In the three months ended March 31, 2011, Dominion reported after-tax net expenses of $62 million for specific items in the Corporate and Other segment, with $54 million of these net expenses attributable to its operating segments.

There were no material net benefit or expense items in the Corporate and Other segment in 2012.

The net expenses for specific items in 2011 primarily related to the impact of the following items:

• A $55 million ($39 million after-tax) impairment charge related to State Line, attributable to Dominion Generation; and

• A $32 million ($19 million after-tax) loss from the operations of Kewaunee, attributable to Dominion Generation. Kewaunee’s results of operations have been reflected in the Corporate and Other segment due to Dominion’s decision in the first quarter of 2011 to pursue the sale of Kewaunee.

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 three months ended March 31, 2012, Virginia Power reported an after-tax benefit of $1 million for specific items attributable to its operating segments in the Corporate and Other segment. Virginia Power recorded no such amounts in its Corporate and Other segment during the three months ended March 31, 2011.

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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 March 31,
2012
Total revenue from external customers	$	930	$	1,675	$	616	$	39		$	232		$	3,492
Intersegment revenue		63		76		200		149			(488	)		—
Total operating revenue		993		1,751		816		188			(256	)		3,492
Net income (loss) attributable to Dominion		166		223		149		(44	)		—			494
2011
Total revenue from external customers	$	1,051	$	1,863	$	834	$	36		$	273		$	4,057
Intersegment revenue		95		70		208		143			(516	)		—
Total operating revenue		1,146		1,933		1,042		179			(243	)		4,057
Net income (loss) attributable to Dominion		149		298		169		(137	)		—			479

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

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

	DVP		Dominion Generation		Corporate and Other		Consolidated Total
(millions)
Three Months Ended March 31,
2012
Operating revenue	$	459	$	1,295	$	—	$	1,754
Net income		107		133		3		243
2011
Operating revenue	$	453	$	1,304	$	—	$	1,757
Net income		113		165		—		278

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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

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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 and other natural disasters, including hurricanes, high winds, severe storms, and earthquakes 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, including costs associated with the disposal of spent nuclear fuel, decommissioning, plant maintenance and changes in existing regulations governing such facilities;

• Unplanned outages of the Companies’ 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 and performance 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, including risks 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;

• 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 ISOs in which Dominion and Virginia Power participate, including changes in rate designs and new and evolving capacity models;

• Political and economic conditions, including inflation and deflation;

• Domestic terrorism and other threats to the Companies’ physical and intangible assets, as well as threats to cybersecurity;

• Industrial, commercial and residential growth or decline in the Companies’ service areas and changes in customer growth or usage patterns, including as a result of energy conservation programs;

• Additional competition in electric markets in which Dominion’s merchant generation facilities operate;

• Changes in technology, particularly with respect to new, developing or alternative sources of generation and smart grid technologies;

• 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 or regulatory proceedings.

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, 2011.

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.

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Accounting Matters

Critical Accounting Policies and Estimates

As of March 31, 2012, 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, 2011. The 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.

Dominion

Results of Operations

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

	2012		2011		$ Change
(millions, except EPS)
First Quarter
Net income attributable to Dominion	$	494	$	479	$	15
Diluted EPS		0.86		0.82		0.04

Overview

First Quarter 2012 vs. 2011

Net income attributable to Dominion increased by 3%. Favorable drivers include the absence of an impairment charge related to State Line recorded in 2011 and a lower effective income tax rate. Unfavorable drivers include lower margins from merchant generation operations and the impact of less favorable weather on electric utility operations.

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Analysis of Consolidated Operations

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

	First Quarter
	2012		2011		$ Change
(millions)
Operating revenue	$	3,492	$	4,057	$	(565	)
Electric fuel and other energy-related purchases		948		1,049		(101	)
Purchased electric capacity		113		119		(6	)
Purchased gas		412		642		(230	)
Net revenue		2,019		2,247		(228	)
Other operations and maintenance		647		861		(214	)
Depreciation, depletion and amortization		287		262		25
Other taxes		170		161		9
Other income		74		57		17
Interest and related charges		228		227		1
Income tax expense		260		310		(50	)

An analysis of Dominion’s results of operations follows:

First Quarter 2012 vs. 2011

Net revenue decreased 10%, primarily reflecting:

• A $121 million decrease from regulated natural gas distribution operations primarily reflecting decreased rider revenue related to low income assistance programs;

• A $99 million decrease from merchant generation operations primarily due to a decrease in realized prices ($65 million) and lower generation ($34 million);

• A $22 million decrease in producer services primarily related to lower physical margins partially offset by favorable price changes on economic hedging positions, all associated with natural gas aggregation, marketing and trading activities; and

• A $19 million decrease from electric utility operations primarily reflecting:

• The impact ($41 million) of a decrease in sales to retail customers primarily due to a decrease in heating degree days ($90 million), partially offset by an increase in sales due to the effect of favorable economic conditions on customer usage and other factors ($49 million); partially offset by

• The impact of rate adjustment clauses ($22 million).

These decreases were partially offset by:

• A $29 million increase in retail energy marketing activities primarily due to price risk management activities.

Other operations and maintenance decreased 25%, primarily reflecting:

• A $99 million decrease in bad debt expense at regulated natural gas distribution operations primarily related to low income assistance programs. These expenses are recovered through rates and do not impact net income; and

• A $55 million decrease due to the absence of an impairment charge recorded in 2011 related to State Line.

Depreciation, depletion and amortization increased 10%, primarily due to property additions.

Income tax expense decreased 16%, primarily reflecting lower pre-tax income and a lower effective income tax rate in 2012.

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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
First Quarter	2012			2011			$ Change			2012			2011			$ Change
(millions, except EPS)
DVP	$	166		$	149		$	17		$	0.29		$	0.26		$	0.03
Dominion Generation		223			298			(75	)		0.39			0.51			(0.12	)
Dominion Energy		149			169			(20	)		0.26			0.29			(0.03	)
Primary operating segments		538			616			(78	)		0.94			1.06			(0.12	)
Corporate and Other		(44	)		(137	)		93			(0.08	)		(0.24	)		0.16
Consolidated	$	494		$	479		$	15		$	0.86		$	0.82		$	0.04

DVP

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

	First Quarter
	2012		2011		% Change
Electricity delivered (million MWh)		19.6		20.9		(6	)%
Degree days (electric distribution service area):
Cooling		26		1		2,500
Heating		1,472		2,068		(29	)
Average electric distribution customer accounts (thousands)(1)		2,448		2,435		1
Average retail energy marketing customer accounts (thousands)(1)		2,122		2,121		—

(1) Period average.

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

	First Quarter 2012 vs. 2011 Increase (Decrease)
	Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	(18	)	$	(0.03	)
Other		6			0.01
FERC transmission equity return		9			0.02
Retail energy marketing operations		20			0.03
Storm damage and service restoration		5			0.01
Other		(5	)		(0.01	)
Change in net income contribution	$	17		$	0.03

Dominion Generation

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

	First Quarter
	2012		2011		% Change
Electricity supplied (million MWh):
Utility		19.6		20.9		(6	)%
Merchant		11.0		11.2		(2	)
Degree days (electric utility service area):
Cooling		26		1		2,500
Heating		1,472		2,068		(29	)

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

	First Quarter 2012 vs. 2011 Increase (Decrease)
	Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	(37	)	$	(0.07	)
Other		15			0.03
Merchant generation margin		(62	)		(0.11	)
PJM ancillary services		(14	)		(0.02	)
Other O&M expenses		18			0.03
Other		5			0.01
Share accretion		—			0.01
Change in net income contribution	$	(75	)	$	(0.12	)

Dominion Energy

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

	First Quarter
	2012		2011		% Change
Gas distribution throughput (bcf):
Sales		12		16		(25	)%
Transportation		98		110		(11	)
Heating degree days (gas distribution service area)		2,309		3,143		(27	)
Average gas distribution customer accounts (thousands)(1):
Sales		256		259		(1	)
Transportation		1,051		1,053		—

(1) Period average.

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

	First Quarter 2012 vs. 2011 Increase (Decrease)
	Amount			EPS
(millions, except EPS)
Producer services margin	$	(14	)	$	(0.02	)
Weather		(6	)		(0.01	)
Change in net income contribution	$	(20	)	$	(0.03	)

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Corporate and Other

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

	First Quarter
	2012			2011			$ Change
(millions, except EPS)
Specific items attributable to operating segments	$	7		$	(54	)	$	61
Specific items attributable to corporate operations		—			(8	)		8
Total specific items		7			(62	)		69
Other corporate operations		(51	)		(75	)		24
Total net benefit (expense)	$	(44	)	$	(137	)	$	93
EPS impact	$	(0.08	)	$	(0.24	)	$	0.16

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 16 to the Consolidated Financial Statements for discussion of these items.

Other Corporate Operations

First Quarter 2012 vs. 2011

Net expenses decreased primarily due to lower state income tax expense and a net gain from the September 2006 hybrids tender offer.

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Virginia Power

Results of Operations

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

	First Quarter
	2012		2011		$ Change
(millions)
Net income	$	243	$	278	$	(35	)

Overview

First Quarter 2012 vs. 2011

Net income decreased by 13% largely due to the impact of less favorable weather, partially offset by the impact of rate adjustment clauses and favorable economic conditions on customer usage and other factors.

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Analysis of Consolidated Operations

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

	First Quarter
	2012		2011		$ Change
(millions)
Operating revenue	$	1,754	$	1,757	$	(3	)
Electric fuel and other energy-related purchases		614		593		21
Purchased electric capacity		113		118		(5	)
Net revenue		1,027		1,046		(19	)
Other operations and maintenance		306		302		4
Depreciation and amortization		188		174		14
Other taxes		65		59		6
Other income		23		29		(6	)
Interest and related charges		100		92		8
Income tax expense		148		170		(22	)

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

First Quarter 2012 vs. 2011

Net revenue decreased 2%, primarily reflecting:

• The impact ($41 million) of a decrease in sales to retail customers primarily due to a decrease in heating degree days ($90 million), partially offset by an increase in sales due to the effect of favorable economic conditions on customer usage and other factors ($49 million); partially offset by

• The impact of rate adjustment clauses ($22 million).

Depreciation and amortization increased 8%, primarily due to property additions.

Income tax expense decreased 13%, primarily reflecting lower pre-tax income in 2012.

Segment Results of Operations

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

	First Quarter
	2012		2011		$ Change
(millions)
DVP	$	107	$	113	$	(6	)
Dominion Generation		133		165		(32	)
Primary operating segments		240		278		(38	)
Corporate and Other		3		—		3
Consolidated	$	243	$	278	$	(35	)

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DVP

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

	First Quarter
	2012		2011		% Change
Electricity delivered (million MWh)		19.6		20.9		(6	)%
Degree days (electric distribution service area):
Cooling		26		1		2,500
Heating		1,472		2,068		(29	)
Average electric distribution customer accounts (thousands)(1)		2,448		2,435		1

(1) Period average.

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

	First Quarter 2012 vs.  2011 Increase (Decrease)
(millions)
Regulated electric sales:
Weather	$	(18	)
Other		6
FERC transmission equity return		9
Storm damage and service restoration		5
Other		(8	)
Change in net income contribution	$	(6	)

Dominion Generation

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

	First Quarter
	2012		2011		% Change
Electricity supplied (million MWh):		19.6		20.9		(6	)%
Degree days (electric utility service area):
Cooling		26		1		2,500
Heating		1,472		2,068		(29	)

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

	First Quarter 2012 vs. 2011 Increase (Decrease)
(millions)
Regulated electric sales:
Weather	$	(37	)
Other		15
PJM ancillary services		(14	)
Other		4
Change in net income contribution	$	(32	)

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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 16 to the Consolidated Financial Statements for discussion of these items.

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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.

At March 31, 2012, Dominion had $2.4 billion of unused capacity under its credit facilities, including $980 million of unused capacity under joint credit facilities available to Virginia Power.

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

	2012			2011
(millions)
Cash and cash equivalents at January 1	$	102		$	62
Cash flows provided by (used in):
Operating activities		1,623			912
Investing activities		(946	)		(752	)
Financing activities		(646	)		(34	)
Net increase in cash and cash equivalents		31			126
Cash and cash equivalents at March 31	$	133		$	188

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

	2012			2011
(millions)
Cash and cash equivalents at January 1	$	29		$	5
Cash flows provided by (used in):
Operating activities		906			524
Investing activities		(558	)		(411	)
Financing activities		(349	)		(38	)
Net increase (decrease) in cash and cash equivalents		(1	)		75
Cash and cash equivalents at March 31	$	28		$	80

Operating Cash Flows

Net cash provided by Dominion’s operating activities increased by $711 million, primarily due to higher deferred fuel cost recoveries in its Virginia jurisdiction, lower margin collateral requirements, income tax refunds received in 2012, and changes in other working capital items, partially offset by lower merchant generation margins and the impact of less favorable weather.

Net cash provided by Virginia Power’s operating activities increased by $382 million, primarily due to higher deferred fuel cost recoveries in its Virginia jurisdiction and net changes in other working capital items. The increase was partially offset by the impact of less favorable weather.

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, 2011.

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 March 31, 2012 for these activities. Gross credit exposure for each counterparty is calculated prior to the application of collateral and represents 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)	$	389	$	70	$	319
Non-investment grade(2)		10		—		10
No external ratings:
Internally rated—investment grade(3)		54		—		54
Internally rated—non-investment grade(4)		78		—		78
Total	$	531	$	70	$	461

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(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 38% of the total net credit exposure.

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

(3) The five largest counterparty exposures, combined, for this category represented approximately 7% of the total net credit exposure.

(4) The five largest counterparty exposures, combined, for this category represented approximately 9% of the total net credit exposure.

Virginia Power’s exposure to potential concentrations of credit risk results primarily from sales to wholesale customers. Gross credit exposure for each counterparty is calculated prior to the application of collateral and represents outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. At March 31, 2012, Virginia Power’s exposure to potential concentrations of credit risk was not considered material.

Investing Cash Flows

Net cash used in Dominion’s investing activities increased by $194 million, primarily due to higher capital expenditures, mainly related to investments in growth projects.

Net cash used in Virginia Power’s investing activities increased by $147 million, primarily due to higher capital expenditures and less restricted cash reimbursements for the purpose of funding certain qualifying construction projects.

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, 2011, 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.

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, as amended. 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 exchange offers or business combination transactions.

Net cash used in Dominion’s financing activities increased by $612 million, primarily due to net debt repayments in 2012 as compared to net debt issuances in 2011 as a result of higher cash inflow from operations, partially offset by the absence of the repurchase of common stock recorded in 2011.

Net cash used in Virginia Power’s financing activities increased by $311 million, primarily due to net debt repayments in 2012 as compared to net debt issuances in 2011 as a result of higher cash inflow from operations.

See Note 11 to the Consolidated Financial Statements for further information regarding Dominion’s and Virginia Power’s credit facilities, liquidity and significant financing transactions.

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, 2011, 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 March 31, 2012, there have been no changes in the Companies’ credit ratings.

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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, 2011, there is a discussion on the various covenants present in the enabling agreements underlying the Companies’ debt. As of March 31, 2012, 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 March 31, 2012, there have been no material changes outside the ordinary course of business to Dominion’s or Virginia Power’s contractual obligations nor any material changes to planned capital expenditures as disclosed in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2011.

Use of Off-Balance Sheet Arrangements

As of March 31, 2012, there have been no material changes in the off-balance sheet arrangements disclosed in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2011.

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, financial condition and/or cash flows. This section should be read in conjunction with Item 1. Business and Future Issues and Other Matters in Item 7. MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2011.

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, 2011 and Note 12 to the Consolidated Financial Statements in this report for additional information on various environmental matters.

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, 2011 and Note 9 to the Consolidated Financial Statements in this report for additional information on various regulatory 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, 2011 and Notes 9 and 12 to the Consolidated Financial Statements for additional information on various legal matters.

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. Non-financial entities that use swaps to hedge or mitigate commercial risk, often referred to as end users, can choose to exempt their hedging transactions from these clearing and exchange trading requirements. In addition, the Dodd-Frank Act allows applicable regulators, including the CFTC and SEC, to impose initial and variation margin requirements on entities who execute swaps. End users were not expressly exempted from these requirements for non-cleared swaps and rules have been proposed that address the margin obligations to be imposed on non-cleared swaps entered with end users. Final rules for the over-the-counter derivative-related provisions of the Dodd-Frank Act, including the clearing, exchange trading and margin requirements and the swap dealer definition, will be established through the ongoing rulemaking process of the applicable regulators. In June 2011, both the CFTC and the SEC confirmed that they would not complete the required rulemakings by the July 2011 deadline under the Dodd-Frank Act. Each agency has granted temporary relief from most derivative-related provisions of the Dodd-Frank Act until the effective date of the applicable rules. Currently, the CFTC’s temporary relief would expire no later than July 16, 2012, if not extended. If, as a result of the rulemaking process, Dominion’s or Virginia Power’s derivative activities are not exempted from the clearing, exchange trading or margin requirements, the Companies could be subject to higher costs, including from higher margin requirements, for their derivative activities. In addition, implementation of, and compliance with, the over-the-counter derivative provisions of the Dodd-Frank Act by the Companies’ swap counterparties could result in increased costs related to the Companies’ derivative activities. While new rules implementing part of the Dodd-Frank Act were recently issued, the Companies are still evaluating the impact of these rules. Additional rules will be issued over the next few months. Due to the ongoing rulemaking process, the Companies are currently unable to assess the potential impact of the Dodd-Frank Act’s derivative-related provisions on their financial condition, results of operations or cash flows.

Cove Point Export Project

In connection with the recent increase in U.S. natural gas production, Dominion is continuing to pursue a liquefaction project at Cove Point, which would enable the facility to liquefy domestically produced natural gas and export it as LNG. In March 2012, Cove Point entered into precedent agreements with two major companies, one of which is Sumitomo Corporation. Between the two companies, the planned project capacity of approximately 750 million cubic feet per day on the inlet and approximately 4.5 to 5 million metric tons per annum on the outlet, is fully subscribed. Pursuant to the precedent agreements, Cove Point would provide liquefaction, storage and loading services but would not own or directly export the LNG. Cove Point is negotiating binding terminal service agreements with the parties, which it expects to complete during the second quarter of this year.

Cove Point has applied to the DOE for authority to export to countries without free trade agreements the equivalent of approximately 1 bcf of natural gas per day over a twenty-five year period. Cove Point plans to submit a request to FERC in the second quarter to initiate the pre-filing process for approval of the project, which could take up to two years. In addition, the project would likely generate opposition from certain environmental and other special interest groups. For example, the Sierra Club has expressed its opposition to LNG export facilities and to the hydraulic fracturing process used to produce much of the natural gas from shale formations.

Subject to a final decision on pursuing the project, execution of binding terminal service agreements, receipt of regulatory and other approvals, and successful completion of engineering studies, construction of liquefaction facilities could begin in 2014 with an in-service date in 2017.

PAGE 62

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 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 or interest rates.

Commodity Price Risk

To manage price risk, Dominion and Virginia Power primarily hold commodity-based financial derivative instruments 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 commodity prices of Dominion’s non-trading commodity-based financial derivative instruments would have resulted in a decrease in fair value of approximately $191 million and $179 million as of March 31, 2012 and December 31, 2011, respectively. A hypothetical 10% unfavorable change in commodity prices of Dominion’s commodity-based financial derivative instruments held for trading purposes would have resulted in a decrease in fair value of approximately $5 million and $8 million as of March 31, 2012 and December 31, 2011, respectively.

A hypothetical 10% unfavorable change in commodity prices would not have resulted in a material change in the fair value of Virginia Power’s non-trading commodity-based financial derivatives as of March 31, 2012 or December 31, 2011.

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 the 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.

Interest Rate Risk

Dominion and Virginia Power manage their interest rate risk exposure predominantly by maintaining a balance of fixed and variable rate debt. They also enter into interest rate sensitive derivatives, including interest rate swaps and interest rate lock agreements. For variable rate debt and interest rate swaps designated under fair value hedging and outstanding for Dominion and Virginia Power, a hypothetical 10% increase in market interest rates would not have resulted in a material change in annual earnings at March 31, 2012 or December 31, 2011.

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Additionally, Dominion and Virginia Power may use forward-starting interest rate swaps and interest rate lock agreements as anticipatory hedges. As of March 31, 2012, Dominion and Virginia Power had $1.9 billion and $840 million, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of approximately $35 million and $16 million, respectively, in the fair value of Dominion’s and Virginia Power’s interest rate derivatives at March 31, 2012.

The impact of a change in interest rates on Dominion’s and Virginia Power’s interest rate-based financial derivative instruments at a point in time is not necessarily representative of the results that will be realized when the contracts are ultimately settled. Net losses from interest rate derivative instruments used for hedging purposes, to the extent realized, will generally be offset by recognition of the hedged transaction.

Investment Price Risk

Dominion and Virginia Power are subject to investment price risk due to securities held as investments in nuclear 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 $41 million, $28 million and $54 million for the three months ended March 31, 2012 and 2011 and for the year ended December 31, 2011, 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. Dominion recorded, in AOCI and regulatory liabilities, a net increase in unrealized gains on these investments of $196 million, $96 million and $52 million for the three months ended March 31, 2012 and 2011 and for the year ended December 31, 2011, respectively.

Virginia Power recognized net realized gains (including investment income) on nuclear decommissioning trust investments of $17 million, $8 million and $24 million for the three months ended March 31, 2012 and 2011 and for the year ended December 31, 2011, 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 $79 million, $39 million, and $25 million for the three months ended March 31, 2012 and 2011 and for the year ended December 31, 2011, 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, each of Dominion’s and Virginia Power’s CEO and CFO have concluded that each of their respective 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.

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. There have been no material changes to the legal proceedings reported in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2011. See the following for discussions on various environmental and other regulatory proceedings to which the Companies are a party:

• Notes 14 and 23 to the Consolidated Financial Statements and Future Issues in MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2011.

• Notes 9 and 12 to the Consolidated Financial Statements in this report.

PAGE 64

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, 2011, 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, 2011. 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.

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

Dominion

ISSUER PURCHASES OF EQUITY SECURITIES

Period	Total Number of Shares (or Units) Purchased(1)		Average Price  Paid per Share (or Unit)(2)		Total Number of Shares  (or Units) Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased under the Plans or Programs(3)
1/1/12-1/31/12		1,754	$	53.08		—	19,629,059 shares/ $1.18 billion
2/1/12-2/29/12		110,663		50.42		—	19,629,059 shares/ $1.18 billion
3/1/12-3/31/12		330		50.41		—	19,629,059 shares/ $1.18 billion
Total		112,747	$	50.46		—	19,629,059 shares/ $1.18 billion

(1) In January, February and March 2012, 1,754 shares, 110,663 shares and 330 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 65

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 Amended and Restated Articles of Incorporation, as in effect on March 3, 2011 (Exhibit 3.1b, Form 10-Q filed April 29, 2011, File No. 1-2255).		X
3.2.a	Dominion Resources, Inc. Amended and Restated Bylaws, effective December 13, 2011 (Exhibit 3.1, Form 8-K filed December 14, 2011, 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, 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); Form of Twenty-First Supplemental Indenture, dated August 1, 2010 (Exhibit 4.3, Form 8-K filed September 1, 2010, File No. 1-2255); Twenty-Second Supplemental Indenture, dated as of January 1, 2012 (Exhibit 4.3, Form 8-K filed January 12, 2012, File No. 1-2255).	X
5.1	Opinion of McGuireWoods LLP regarding Legality (filed herewith).	X
10.1	DRS Services Agreement, dated January 1, 2012, between Dominion Resources Services, Inc. and Virginia Electric and Power Company (Exhibit 10.2, Form 10-K for the fiscal year ended December 31, 2011, File No. 1-2255 and File No. 1-8489).	X	X
10.2*	2012 Long-Term Incentive Program - 2012 Performance Grant Plan (Exhibit 10.1, Form 8-K filed January 20, 2012, File No. 1-8489).	X	X
10.3*	2012 Long-Term Incentive Program - Form of 2012 Restricted Stock Award Agreement (Exhibit 10.2, Form 8-K filed January 20, 2012, File No. 1-8489).	X	X

PAGE 66

12.1	Ratio of earnings to fixed charges for Dominion Resources, Inc. (filed herewith).	X
12.2.a	Ratio of earnings to fixed charges for Virginia Electric and Power Company (filed herewith).		X
12.2.b	Ratio of earnings to fixed charges and dividends for Virginia Electric and Power Company (filed herewith).		X
23.1	Consent of McGuire Woods LLP (contained in Exhibit 5.1).	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
101^	The following financial statements from Dominion Resources, Inc.’s and Virginia Electric and Power Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012, filed on April 26, 2012, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Statements of Common Shareholders’ Equity (iii) Consolidated Balance Sheets, (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements.	X	X

* Indicates management contract or compensatory plan or arrangement

^ 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 67

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
April 26, 2012	/s/ Ashwini Sawhney
	Ashwini Sawhney Vice President – Accounting and Controller (Chief Accounting Officer)
	VIRGINIA ELECTRIC AND POWER COMPANY Registrant
April 26, 2012	/s/ Ashwini Sawhney
	Ashwini Sawhney Vice President – Accounting (Chief Accounting Officer)

PAGE 68

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 Amended and Restated Articles of Incorporation, as in effect on March 3, 2011 (Exhibit 3.1b, Form 10-Q filed April 29, 2011, File No. 1-2255).		X
3.2.a	Dominion Resources, Inc. Amended and Restated Bylaws, effective December 13, 2011 (Exhibit 3.1, Form 8-K filed December 14, 2011, 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, 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); Form of Twenty-First Supplemental Indenture, dated August 1, 2010 (Exhibit 4.3, Form 8-K filed September 1, 2010, File No. 1-2255); Twenty-Second Supplemental Indenture, dated as of January 1, 2012 (Exhibit 4.3, Form 8-K filed January 12, 2012, File No. 1-2255).	X
5.1	Opinion of McGuireWoods LLP regarding Legality (filed herewith).	X
10.1	DRS Services Agreement, dated January 1, 2012, between Dominion Resources Services, Inc. and Virginia Electric and Power Company (Exhibit 10.2, Form 10-K for the fiscal year ended December 31, 2011, File No. 1-2255 and File No. 1-8489).	X	X
10.2*	2012 Long-Term Incentive Program - 2012 Performance Grant Plan (Exhibit 10.1, Form 8-K filed January 20, 2012, File No. 1-8489).	X	X
10.3*	2012 Long-Term Incentive Program - Form of 2012 Restricted Stock Award Agreement (Exhibit 10.2, Form 8-K filed January 20, 2012, File No. 1-8489).	X	X
12.1	Ratio of earnings to fixed charges for Dominion Resources, Inc. (filed herewith).	X

PAGE 69

12.2.a	Ratio of earnings to fixed charges for Virginia Electric and Power Company (filed herewith).		X
12.2.b	Ratio of earnings to fixed charges and dividends for Virginia Electric and Power Company (filed herewith).		X
23.1	Consent of McGuire Woods LLP (contained in Exhibit 5.1).	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
101^	The following financial statements from Dominion Resources, Inc.’s and Virginia Electric and Power Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012, filed on April 26, 2012, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Statements of Common Shareholders’ Equity (iii) Consolidated Balance Sheets, (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements.	X	X

* Indicates management contract or compensatory plan or arrangement

^ 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 70

EX-5.1

Exhibit 5.1

McGuireWoods LLP   One James Center   901 East Cary Street   Richmond, VA 23219-4030   Phone: 804.775.1000   Fax: 804.775.1061   www.mcguirewoods.com

April 26, 2012

Dominion Resources, Inc.

120 Tredegar Street

Richmond, Virginia 23219

Ladies and Gentlemen:

We have acted as special counsel to Dominion Resources, Inc., a Virginia corporation (the “Company”), in connection with (i) the Registration Statement on Form S-3 (File No. 333-179213) (the “Registration Statement”), which was filed by the Company with the Securities and Exchange Commission (the “SEC”) in connection with the registration under the Securities Act of 1933, as amended (the “Act”), of certain securities, including the Company’s common stock (without par value) and (ii) the offer and sale by the Company of up to $500,000,000 of the Company’s common stock (the “Shares”) in privately negotiated transactions or through “at the market” offerings as described in the Company’s Prospectus, dated January 27, 2012 (the “Prospectus”) and Prospectus Supplement dated February 28, 2012 (the “Prospectus Supplement”). The Registration Statement became effective on January 27, 2012. This opinion letter is being furnished in accordance with the requirements of Item 16 of Form S-3 and Item 601(b)(5)(i) of Regulation S-K promulgated under the Act.

The Shares are being offered to the public in accordance with four separate Sales Agency Agreements, the form of which is filed as Exhibit 1.2 to the Registration Statement, between the Company and sales agents as may be named from time to time in the Company’s Annual Reports on Form 10-K and Quarterly Reports on Form 10-Q (the “Sales Agreements”). The sales agents currently named are BNY Mellon Capital Markets, LLC, Merrill Lynch, Pierce, Fenner & Smith Incorporated, Morgan Stanley & Co. LLC and Goldman, Sachs & Co. Capitalized terms used and not defined herein shall have the meanings assigned to them in the Registration Statement or the Sales Agreements.

Documents Reviewed

In connection with this opinion letter, we have examined the following documents:

(a) the Registration Statement;

(b) the Prospectus;

(c) the Prospectus Supplement; and

(d) the Sales Agreements.

Dominion Resources, Inc.

April 26, 2012

Page 2

In addition we have examined and relied upon the following:

(i) a certificate from the assistant secretary of the Company certifying as to (A) true and correct copies of the articles of incorporation and bylaws of the Company (the “Organizational Documents”) and (B) the resolutions of the Board of Directors of the Company effective January 20, 2012 authorizing the filing of the Registration Statement and the resolutions of authorized officers of the Company effective January 27, 2012 (the “Authorizing Resolutions”) relating to the offer and sale of the Shares by the Company under the Sales Agreements;

(ii) a certificate dated April 26, 2012 issued by the SCC, attesting to the corporate status and good standing of the Company in the Commonwealth of Virginia (the “Status Certificate”); and

(iii) originals, or copies identified to our satisfaction as being true copies, of such other records, documents and instruments as we have deemed necessary for the purposes of this opinion letter.

“Applicable Law” means the law of the Commonwealth of Virginia and the relevant laws of the United States.

Assumptions Underlying Our Opinions

For all purposes of the opinions expressed herein, we have assumed, without independent investigation, the following:

(a) Factual Matters. To the extent that we have reviewed and relied upon (i) certificates of the Company or authorized representatives thereof and (ii) certificates and assurances from public officials, all of such certificates, representations and assurances are accurate with regard to factual matters.

(b) Signatures. The signatures of individuals who have signed the Sales Agreements are genuine and (other than those of individuals signing on behalf of the Company) authorized.

(c) Authentic and Conforming Documents. All documents submitted to us as originals are authentic, complete and accurate, and all documents submitted to us as copies conform to authentic original documents.

(d) Organizational Status, Power and Authority and Legal Capacity of Certain Parties. All parties to the Sales Agreements are validly existing and in good standing in their respective jurisdictions of formation and have the capacity and full power and authority to execute, deliver and perform the Sales Agreements and the documents required or permitted to be delivered and performed thereunder, except that no such assumption is made as to the Company as of the date hereof. All individuals who have signed each Sales Agreement had the legal capacity to execute such Sales Agreement.

Dominion Resources, Inc.

April 26, 2012

Page 3

(e) Authorization, Execution and Delivery of Sales Agreements. The Sales Agreements and the documents required or permitted to be delivered thereunder have been duly authorized by all necessary corporate, limited liability company, business trust, partnership or other action on the part of the parties thereto and have been duly executed and delivered by such parties, except that no such assumption is made as to the Company.

(f) Sales Agreements Binding on Certain Parties. The Sales Agreements and the documents required or permitted to be delivered thereunder are valid and binding obligations enforceable against the parties thereto in accordance with their terms, except no such assumption is made as to the Company.

(g) Noncontravention. Neither the offer and sale of the Shares by the Company or the execution and delivery of the Sales Agreements by any party thereto nor the performance by such party of its obligations thereunder will conflict with or result in a breach of (i) the certificate or articles of incorporation, bylaws, certificate or articles of organization, operating agreement, certificate of limited partnership, partnership agreement, trust agreement or other similar organizational documents of any such party, except that no such assumption is made with respect to the Company as to its Organizational Documents, (ii) any law or regulation of any jurisdiction applicable to any such party, except that no such assumption is made with respect to the Company as to any Applicable Law or (iii) any order, writ, injunction or decree of any court or governmental instrumentality or agency applicable to any such party or any agreement or instrument to which any such party may be a party or by which its properties are subject or bound, except that no such assumption is made with respect to the Company as to the Sales Agreements.

(h) Governmental Approvals. All consents, approvals and authorizations of, or filings with, all governmental authorities that are required as a condition to the offer and sale of the Shares or to the execution and delivery of the Sales Agreements by the parties thereto or the performance by such parties of their obligations thereunder have been obtained or made, except that no such assumption is made with respect to any consent, approval, authorization or filing that is applicable to the Company.

(i) No Mutual Mistake, Amendments, etc. There has not been any mutual mistake of fact, fraud, duress or undue influence in connection with the offer and sale of the Shares as contemplated by the Registration Statement, Prospectus and the Prospectus Supplement. There are no oral or written statements or agreements that modify, amend or vary, or purport to amend or vary, any of the terms of the Sales Agreements.

Our Opinions

Based on and subject to the foregoing and the exclusions, qualifications, limitations and other assumptions set forth in this opinion letter, we are of the opinion that:

1. Organizational Status. Based solely upon its Status Certificate, the Company is a validly existing corporation under the laws of the Commonwealth of Virginia, and is in good standing under such laws.

Dominion Resources, Inc.

April 26, 2012

Page 4

2. Power and Authority. The Company has the corporate power and authority to issue the Shares.

3. Validity. When (i) the Shares have been issued and sold as contemplated by the Registration Statement, the Prospectus and the Prospectus Supplement, (ii) the Company has received the consideration provided for in the Prospectus Supplement and the Sales Agreements, (iii) such consideration per share is not less than the amount specified in the applicable Authorizing Resolutions and (iv) certificates in the form required under the laws of the Commonwealth of Virginia representing the Shares are duly executed, countersigned, registered and delivered, if such Shares are certificated, such Shares will be validly issued, fully paid and non-assessable.

Qualification and Limitation Applicable to Our Opinions

The opinions set forth above are limited to the Applicable Law, and we do not express any opinion concerning any other law.

Miscellaneous

The foregoing opinion is being furnished only for the purpose referred to in the first paragraph of this opinion letter. We hereby consent to the filing of this opinion as an exhibit to the Company’s Quarterly Report on Form 10-Q and the incorporation of this opinion by reference in the Registration Statement and to references to us under the heading “Legal Matters” in the Registration Statement and in the Prospectus Supplement relating to the Shares. In giving this consent, we do not admit that we are within the category of persons whose consent is required by Section 7 of the Securities Act or the rules and regulations of the SEC promulgated thereunder.

Very truly yours,

/s/ McGuireWoods LLP

EX-12.1

Exhibit 12.1

Dominion Resources Inc. and Subsidiaries

Computation of Ratio of Earnings to Fixed Charges

(millions of dollars)

	Three Months Ended March 31, 2012 (a)			Twelve Months Ended March 31, 2012 (b)			Years Ended December, 31
							2011 (c)			2010 (d)			2009(e)			2008(f)			2007(g)
Earnings, as defined:
Income from continuing operations including noncontrolling interest before income taxes, extraordinary item and cumulative effect of change in accounting principle	$	761		$	2,139		$	2,171		$	5,037		$	1,874		$	2,613		$	4,442
Distributed income from unconsolidated investees, less equity in earnings		(6	)		(32	)		(23	)		(30	)		(30	)		(39	)		(20	)
Fixed charges, as defined		257			996			1,003			971			1,022			990			1,325
Capitalized interest		(8	)		(36	)		(37	)		(27	)		(18	)		(44	)		(73	)
Preference security dividend requirement of consolidated subsidiary		(6	)		(24	)		(25	)		(28	)		(24	)		(26	)		(26	)
Total earnings, as defined	$	998		$	3,043		$	3,089		$	5,923		$	2,824		$	3,494		$	5,648
Fixed charges, as defined:
Interest charges	$	242		$	928		$	928		$	886		$	941		$	911		$	1,238
Preference security dividend requirement of consolidated subsidiary		6			24			25			28			24			26			26
Rental interest factor		9			44			50			57			57			53			61
Total fixed charges, as defined	$	257		$	996		$	1,003		$	971		$	1,022		$	990		$	1,325
Ratio of Earnings to Fixed Charges		3.88			3.06			3.08			6.10			2.76			3.53			4.26

(a) Earnings for the three months ended March 31, 2012 include an $11 million net gain related to our investments in nuclear decommissioning trust funds. Excluding this item from the calculation would result in a lower ratio of earnings to fixed charges for the three months ended March 31, 2012.

(b) Earnings for the twelve months ended March 31, 2012 include a $228 million of impairment charges related to generation assets; $96 million of restoration costs associated with Hurricane Irene; $57 million impairment of excess emission allowances resulting from a new EPA Air Pollution Rule; $33 million for severance and other costs resulting from expected closings of our Salem Harbor and State Line merchant generation plants; $31 million net charge in connection with the Virginia Commission’s final ruling associated with its biennial review of Virginia Power’s base rates for 2009 and 2010 test years; $21 million of earthquake related costs, largely related to inspections following the safe shutdown of reactors at our North Anna nuclear power station; and $44 million net charge related to other items; partially offset by a $24 million benefit related to litigation with the Department of Energy for spent nuclear fuel-related costs at our Millstone nuclear power station. Excluding these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended March 31, 2012.

(c) Earnings for the twelve months ended December 31, 2011 include $283 million of impairment charges related to generation assets; $96 million of restoration costs associated with Hurricane Irene; $57 million impairment of excess emission allowances resulting from a new EPA Air Pollution Rule; $33 million for severance and other costs resulting from expected closings of our Salem Harbor and State Line merchant generation plants; $31 million net charge in connection with the Virginia Commission’s final ruling associated with its biennial review of Virginia Power’s base rates for 2009 and 2010 test years; $21 million of earthquake related costs, largely related to inspections following the safe shutdown of reactors at our North Anna nuclear power station; and $45 million net charge related to other items; partially offset by a $24 million benefit related to litigation with the Department of Energy for spent nuclear fuel-related costs at our Millstone nuclear power station. Excluding these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2011.

(d) Earnings for the twelve months ended December 31, 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, $194 million of charges related to our State Line and Salem Harbor merchant power stations, and a $1 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 December 31, 2010.

(e) 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.

(f) 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.

(g) 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.

EX-12.2.A

Exhibit 12.2.a

Virginia Electric and Power Company

Computation of Ratio of Earnings to Fixed Charges

(millions of dollars)

	Three Months Ended March 31, 2012		Twelve Months Ended March 31, 2012		Years Ended December 31,
					2011		2010		2009		2008		2007
Earnings, as defined:
Income from continuing operations before income taxes, extraordinary item and cumulative effect of change in accounting principle	$	391	$	1,305	$	1,362	$	1,394	$	503	$	1,364	$	977
Fixed charges as defined		108		367		361		385		392		343		332
Capitalized interest		—		—		—		—		—		—		(4	)
Total earnings, as defined	$	499	$	1,672	$	1,723	$	1,779	$	895	$	1,707	$	1,305
Fixed charges, as defined:
Interest charges	$	104	$	353	$	346	$	368	$	376	$	330	$	320
Rental interest factor		4		14		15		17		16		13		12
Total fixed charges, as defined	$	108	$	367	$	361	$	385	$	392	$	343	$	332
Ratio of Earnings to Fixed Charges		4.62		4.56		4.77		4.62		2.28		4.98		3.93

EX-12.2.B

Exhibit 12.2.b

Virginia Electric and Power Company

Computation of Ratio of Earnings to Fixed Charges and Preferred Dividends

(millions of dollars)

	Three Months Ended March 31, 2012			Twelve Months Ended March 31, 2012			Years Ended December 31,
							2011			2010			2009			2008			2007
Earnings, as defined:
Income from continuing operations before income taxes, extraordinary item and cumulative effect of change in accounting principle	$	391		$	1,305		$	1,362		$	1,394		$	503		$	1,364		$	977
Fixed charges as defined		115			394			388			412			416			369			357
Capitalized interest		—			—			—			—			—			—			(4	)
Preference security dividend requirement		(7	)		(27	)		(27	)		(27	)		(24	)		(26	)		(25	)
Total earnings, as defined	$	499		$	1,672		$	1,723		$	1,779		$	895		$	1,707		$	1,305
Fixed charges, as defined:
Interest charges	$	104		$	353		$	346		$	368		$	376		$	330		$	320
Preference security dividend requirement		7			27			27			27			24			26			25
Rental interest factor		4			14			15			17			16			13			12
Total fixed charges, as defined	$	115		$	394		$	388		$	412		$	416		$	369		$	357
Ratio of Earnings to Fixed Charges and Preferred Dividends		4.34			4.24			4.44			4.32			2.15			4.63			3.66

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: April 26, 2012	/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: April 26, 2012	/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: April 26, 2012	/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: April 26, 2012	/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 March 31, 2012 (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 March 31, 2012 and for the period then ended.

/s/ Thomas F. Farrell II

Thomas F. Farrell II

President and Chief Executive Officer

April 26, 2012

/s/ Mark F. McGettrick

Mark F. McGettrick

Executive Vice President and Chief Financial Officer

April 26, 2012

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 March 31, 2012 (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 March 31, 2012 and for the period then ended.

/s/ Thomas F. Farrell II

Thomas F. Farrell II

Chief Executive Officer

April 26, 2012

/s/ Mark F. McGettrick

Mark F. McGettrick

Executive Vice President and Chief Financial Officer

April 26, 2012

EX-99

Exhibit 99

DOMINION RESOURCES, INC.

CONDENSED CONSOLIDATED EARNINGS STATEMENT

(Unaudited)

	Twelve Months Ended March 31, 2012
(millions, except per share amounts)
Operating Revenue	$	13,814
Operating Expenses		11,001
Income from operations		2,813
Other income		196
Interest and related charges		870
Income before income tax expense including noncontrolling interests	$	2,139
Income tax expense		694
Net income including noncontrolling interests		1,445
Noncontrolling interests		21
Net income attributable to Dominion	$	1,424
Amounts attributable to Dominion:
Income from continuing operations	$	1,424
Net income attributable to Dominion	$	1,424
Earnings Per Common Share – Basic
Income from continuing operations	$	2.53
Noncontrolling interests		(0.04	)
Net income attributable to Dominion	$	2.49
Earnings Per Common Share – Diluted
Income from continuing operations	$	2.52
Noncontrolling interests		(0.04	)
Net income attributable to Dominion	$	2.48

Exhibit 99

VIRGINIA ELECTRIC AND POWER COMPANY

CONDENSED CONSOLIDATED EARNINGS STATEMENT

(Unaudited)

	Twelve Months Ended March 31, 2012
(millions)
Operating Revenue	$	7,243
Operating Expenses		5,681
Income from operations		1,562
Other income		82
Interest and related charges		339
Income before income tax expense		1,305
Income tax expense		518
Net Income		787
Preferred dividends		16
Balance available for common stock	$	771

XML

Earnings Per Share (Narrative) (Details)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Earnings Per Share [Abstract]
Potentially dilutive securities not included in the calculation of diluted EPS because the exercise or purchase prices were greater than the average market price of our common shares	0	0

XML

Investments (Fair Value of our Marketable Debt Securities by Contractual Maturity) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012
Investments, Debt and Equity Securities [Abstract]
Due in one year or less	$ 62
Due after one year through five years	324
Due after five years through ten years	338
Due after ten years	377
Total	$ 1,101

XML

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
AOCI After-Tax	$ 58
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	49
Commodity Contract | Gas Energy Contract
AOCI After-Tax	(30)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	(16)
Maximum Length of Time Hedged in Cash Flow Hedge	33 months
Commodity Contract | Electricity Energy Contract
AOCI After-Tax	243
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	102
Maximum Length of Time Hedged in Cash Flow Hedge	45 months
Commodity Contract | NGLs Contract
AOCI After-Tax	(64)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	(27)
Maximum Length of Time Hedged in Cash Flow Hedge	33 months
Commodity Contract | Other Energy Contract
AOCI After-Tax	6
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	2
Maximum Length of Time Hedged in Cash Flow Hedge	38 months
Interest Rate Contract
AOCI After-Tax	(97)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$ (12)
Maximum Length of Time Hedged in Cash Flow Hedge	369 months

XML

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Available-for-sale securities:
Proceeds from sales	$ 415		$ 502
Realized gains	28	[1]	14	[1]
Realized losses	$ 4	[1]	$ 8	[1]

[1] Includes realized gains or losses recorded to the decommissioning trust regulatory liability.

XML

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		12 Months Ended
	Mar. 31, 2012		Dec. 31, 2011
Long-term debt - VIE	$ 882		$ 890	[1]
Junior subordinated notes payable to affiliates	268		268	[1]
Enhanced junior subordinated notes	1,365		1,451	[1]
Subsidiary preferred stock	257		257	[1]
Valuation of certain fair value hedges	93		105
Issuance expenses of subsidiary preferred stock	2		2
Carrying Amount
Long-term debt, including securities due within one year	16,695	[2]	16,264	[2]
Long-term debt - VIE	882	[3]	890	[3]
Junior subordinated notes payable to affiliates	268		268
Enhanced junior subordinated notes	1,365		1,451
Subsidiary preferred stock	257	[4]	257	[4]
Estimate of Fair Value
Long-term debt, including securities due within one year	19,256	[2],[5]	18,936	[2],[5]
Long-term debt - VIE	889	[3],[5]	892	[3],[5]
Junior subordinated notes payable to affiliates	272	[5]	268	[5]
Enhanced junior subordinated notes	1,437	[5]	1,518	[5]
Subsidiary preferred stock	$ 259	[4],[5]	$ 256	[4],[5]

[1] Dominion’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

[2] Includes amounts which represent the unamortized discount and premium. At March 31, 2012 and December 31, 2011, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $93 million and $105 million, respectively.

[3] Includes amounts which represent the unamortized premium.

[4] Includes deferred issuance expenses of $2 million at March 31, 2012 and December 31, 2011.

[5] Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. 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.

XML

Related Party Transactions (Tables) (Virginia Electric and Power Company [Member])

3 Months Ended

Mar. 31, 2012

Virginia Electric and Power Company [Member]

Related Party Transaction [Line Items]

Transactions With Affiliates

Presented below are significant transactions with DRS and other affiliates:

	Three Months Ended March 31,
	2012		2011
(millions)
Commodity purchases from affiliates	$	78	$	62
Services provided by affiliates	96		93

XML

Variable Interest Entities (Narrative) (Details) (Virginia Electric and Power Company [Member], USD $)	3 Months Ended
	Mar. 31, 2012 MW	Mar. 31, 2011
Virginia Electric and Power Company [Member]
Long term capacity contract non utility generators	4
Aggregate generation capacity from long-term power and capacity contracts (MW)	870
Contracts expiry date start range	2015
Contracts expiry date end range	2021
Remaining purchase commitments	$ 1,200,000,000
Payment for electric capacity	55,000,000	53,000,000
Payment for electric energy	19,000,000	39,000,000
Shared services purchased	$ 96,000,000	$ 93,000,000

XML

Operating Revenue (Tables)

3 Months Ended

Mar. 31, 2012

Regulated and Unregulated Operating Revenue [Abstract]

Operating Revenue, Table

The Companies’ operating revenue consists of the following:

	Three Months Ended March 31,
	2012		2011
(millions)
Dominion
Electric sales:
Regulated	$	1,724	$	1,730
Nonregulated	738		941
Gas sales:
Regulated	99		139
Nonregulated	398		602
Gas transportation and storage	405		538
Other	128		107
Total operating revenue	$	3,492	$	4,057
Virginia Power
Regulated electric sales	$	1,724	$	1,730
Other	30		27
Total operating revenue	$	1,754	$	1,757

XML

Derivatives and Hedge Accounting Activities (Gains and Losses on Derivatives in Cash Flow Hedging Relationships) (Details) (Cash Flow Hedges, USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	$ 208	[1]	$ (143)	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	28		(18)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	26	[2]	(6)	[2]
Commodity Contract [Member]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	176	[1]	(142)	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	27		(18)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	(1)	[2]	(5)	[2]
Commodity Contract [Member] | Operating Revenue [Member]
Amount of Gain (Loss) Reclassified from AOCI to Income	64		28
Commodity Contract [Member] | Purchased Gas [Member]
Amount of Gain (Loss) Reclassified from AOCI to Income	(30)		(48)
Commodity Contract [Member] | Electric Fuel and Other Energy-Related Purchases
Amount of Gain (Loss) Reclassified from AOCI to Income	(7)		1
Commodity Contract [Member] | Purchased Electric Capacity
Amount of Gain (Loss) Reclassified from AOCI to Income			1
Interest Rate Contract [Member]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	32	[1],[3]	(1)	[1],[3]
Amount of Gain (Loss) Reclassified from AOCI to Income	1	[3]	0	[3]
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	$ 27	[2],[3]	$ (1)	[2],[3]

[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.

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Fair Value Measurements Fair Value, Option, Quantitative Disclosures (Details) (USD $)	3 Months Ended
	Mar. 31, 2012
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	$ 117,000,000
Fair Value of Derivative Liabilities	178,000,000
Natural Gas | Physical Financial Fowards Futures
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	31,000,000	[1]
Fair Value of Derivative Liabilities	21,000,000	[1]
Natural Gas | Physical Financial Options
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	6,000,000
Fair Value of Derivative Liabilities	14,000,000	[1]
Electricity | Physical Financial Fowards Futures
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	69,000,000
Fair Value of Derivative Liabilities	17,000,000
FTRs | Physical Financial Fowards Futures
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	1,000,000
Fair Value of Derivative Liabilities	18,000,000
Capacity | Physical Financial Fowards Futures
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	9,000,000
Liquids | Physical Financial Fowards Futures
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	1,000,000
Fair Value of Derivative Liabilities	108,000,000
Fair Value, Option, Quantitative Disclosures, Assets | Natural Gas | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	(1)	[1],[2]
Fair Value, Option, Quantitative Disclosures, Assets | Natural Gas | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	6	[1],[2]
Fair Value, Option, Quantitative Disclosures, Assets | Natural Gas | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	3	[1],[2]
Fair Value, Option, Quantitative Disclosures, Assets | Natural Gas | Physical Financial Options | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	2	[2]
Price Volatility	23.00%	[2],[3]
Price Correlation	100.00%	[2],[4]
Fair Value, Option, Quantitative Disclosures, Assets | Natural Gas | Physical Financial Options | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	5	[2]
Price Volatility	60.00%	[2],[3]
Price Correlation	100.00%	[2],[4]
Fair Value, Option, Quantitative Disclosures, Assets | Natural Gas | Physical Financial Options | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	4	[2]
Price Volatility	30.00%	[2],[3]
Price Correlation	100.00%	[2],[4]
Fair Value, Option, Quantitative Disclosures, Assets | Electricity | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	21	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Electricity | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	61	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Electricity | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	43	[2]
Fair Value, Option, Quantitative Disclosures, Assets | FTRs | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	(3)	[2]
Fair Value, Option, Quantitative Disclosures, Assets | FTRs | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	3	[2]
Fair Value, Option, Quantitative Disclosures, Assets | FTRs | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	0	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Capacity | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	95	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Capacity | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	120	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Capacity | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	101	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Liquids | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	1	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Liquids | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	2	[2]
Fair Value, Option, Quantitative Disclosures, Assets | Liquids | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	1	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Natural Gas | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	(1)	[1],[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Natural Gas | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	6	[1],[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Natural Gas | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	3	[1],[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Natural Gas | Physical Financial Options | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	(1)	[1],[2]
Price Volatility	23.00%	[2],[3]
Price Correlation	70.00%	[2],[4]
Fair Value, Option, Quantitative Disclosures, Liabilities | Natural Gas | Physical Financial Options | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	5	[1],[2]
Price Volatility	59.00%	[2],[3]
Price Correlation	100.00%	[2],[4]
Fair Value, Option, Quantitative Disclosures, Liabilities | Natural Gas | Physical Financial Options | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	2	[1],[2]
Price Volatility	36.00%	[2],[3]
Price Correlation	90.00%	[2],[4]
Fair Value, Option, Quantitative Disclosures, Liabilities | Electricity | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	12	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Electricity | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	61	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Electricity | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	41	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | FTRs | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	(6)	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | FTRs | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	5	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | FTRs | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	0	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Liquids | Physical Financial Fowards Futures | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	1	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Liquids | Physical Financial Fowards Futures | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	3	[2]
Fair Value, Option, Quantitative Disclosures, Liabilities | Liquids | Physical Financial Fowards Futures | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price	$ 2	[2]

[1] Includes basis.

[2] Averages weighted by volume.

[3] Represents volatilities unrepresented in published markets.

[4] Represents intra-price correlations for which markets do not exist.

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Income Taxes (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
Operating Loss Carryforwards [Line Items]
Option Price To Purchase Generating Facility At End Of Lease	$ 923
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Reduction of valuation allowance	$ 20

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Investments (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Mar. 31, 2012 Categories of Investments, Marketable Securities, Trading Securities [Member]	Dec. 31, 2011 Categories of Investments, Marketable Securities, Trading Securities [Member]	Mar. 31, 2012 Categories of Investments, Cost-method Investments [Member]	Dec. 31, 2011 Categories of Investments, Cost-method Investments [Member]
Investments held in our rabbi trusts			$ 95	$ 90	$ 16	$ 17
Net unrealized gains on trading securities	$ 4	$ 3

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Operating Segments (Schedule of Segment Reporting Information, by Segment) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Total revenue from external customers	$ 3,492	$ 4,057
Intersegment revenue	0	0
Total operating revenue	3,492	4,057
Net Income (Loss) Attributable to Parent	494	479
Dominion Virginia Power
Total revenue from external customers	930	1,051
Intersegment revenue	63	95
Total operating revenue	993	1,146
Net Income (Loss) Attributable to Parent	166	149
Dominion Generation
Total revenue from external customers	1,675	1,863
Intersegment revenue	76	70
Total operating revenue	1,751	1,933
Net Income (Loss) Attributable to Parent	223	298
Dominion Energy
Total revenue from external customers	616	834
Intersegment revenue	200	208
Total operating revenue	816	1,042
Net Income (Loss) Attributable to Parent	149	169
Corporate and Other
Total revenue from external customers	39	36
Intersegment revenue	149	143
Total operating revenue	188	179
Net Income (Loss) Attributable to Parent	(44)	(137)
Adjustments/ Eliminations
Total revenue from external customers	232	273
Intersegment revenue	(488)	(516)
Total operating revenue	(256)	(243)
Net Income (Loss) Attributable to Parent	$ 0	$ 0

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Commitments and Contingencies (Subsidiary Guarantees) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012
Stated Limit	$ 4,435
Value	742	[1]
Subsidiary Debt
Stated Limit	363	[2]
Value	363	[1],[2]
Commodity Transactions
Stated Limit	3,360	[3]
Value	273	[1],[3]
Nuclear Obligations
Stated Limit	231	[4]
Value	62	[1],[4]
Other
Stated Limit	481	[5]
Value	44	[1],[5]
Millstone Power Station | Nuclear Obligations
Stated Limit	150
Kewaunee Power Station | Nuclear Obligations
Stated Limit	60
Third Party and Equity Method Investee [Member]
Stated Limit	$ 45

[1] Represents the estimated portion of the guarantee's stated limit that is utilized as of March 31, 2012 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, including subsidiaries of Virginia Power and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and 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 limits.

[4] 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.

[5] 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.

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Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Details) (USD $)	Mar. 31, 2012
Current Derivative Contract
Interest rate	$ 2,000,000,000
Current Derivative Contract | Natural Gas | Fixed Price
Volume of natural gas (cf)/ liquids (gallons)	315,000,000,000	[1]
Current Derivative Contract | Natural Gas | Basis
Volume of natural gas (cf)/ liquids (gallons)	861,000,000,000	[1]
Current Derivative Contract | Electricity | Fixed Price
Volume of electricity (MWh)	21,953,642	[1]
Current Derivative Contract | Electricity | Financial Transmission Rights
Volume of electricity (MWh)	21,805,241
Current Derivative Contract | Capacity
Capacity (MW)	63,825
Current Derivative Contract | Liquids
Volume of natural gas (cf)/ liquids (gallons)	137,508,000	[2]
Noncurrent Derivative Contract
Interest rate	$ 1,940,000,000
Noncurrent Derivative Contract | Natural Gas | Fixed Price
Volume of natural gas (cf)/ liquids (gallons)	74,000,000,000	[1]
Noncurrent Derivative Contract | Natural Gas | Basis
Volume of natural gas (cf)/ liquids (gallons)	484,000,000,000	[1]
Noncurrent Derivative Contract | Electricity | Fixed Price
Volume of electricity (MWh)	21,718,420	[1]
Noncurrent Derivative Contract | Electricity | Financial Transmission Rights
Volume of electricity (MWh)	810,816
Noncurrent Derivative Contract | Capacity
Capacity (MW)	272,968
Noncurrent Derivative Contract | Liquids
Volume of natural gas (cf)/ liquids (gallons)	221,214,000	[2]

[1] Includes options.

[2] Includes NGLs and oil.

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Significant Accounting Policies

3 Months Ended

Mar. 31, 2012

Accounting Policies [Abstract]

Significant Accounting Policies

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, 2011.

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 March 31, 2012 and their results of operations and cash flows for the three months ended March 31, 2012 and 2011. 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 and those VIEs where Dominion has been determined to be the primary beneficiary.

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 2011 Consolidated Financial Statements and Notes have been reclassified to conform to the 2012 presentation for comparative purposes. The reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows.

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

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Credit Risk (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$ 531
Concentration Risk Credit Risk Financial Instrument Maximum Exposure Net	461
Additional Collateral, Aggregate Fair Value	71	88
Collateral Already Posted, Aggregate Fair Value	145	110
Pledged Financial Instruments, Not Separately Reported, Securities for Letter of Credit Facilities	4	4
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	$ 277	$ 259
Investment Grade [Member] | Credit Concentration Risk [Member]
Concentration Risk, Percentage	81.00%
Investment Grade [Member] | Counterparty, A [Member]
Concentration Risk, Percentage	11.00%

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Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012		Dec. 31, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	$ 117
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	4,604		4,192
Total liabilities	1,110		1,157
Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	1,178		965
Derivative Liabilities	934		888
Fair Value, Measurements, Recurring | Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	94		105
Derivative Liabilities	176		269
Fair Value, Measurements, Recurring | Equity Securities | Large cap | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	1,933	[1]	1,718	[1]
Fair Value, Measurements, Recurring | Equity Securities | Large cap | Non United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	11	[1]	10	[1]
Fair Value, Measurements, Recurring | Equity Securities | Equity securities, other | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	59	[1]	51	[1]
Fair Value, Measurements, Recurring | Fixed Income Securities | Corporate Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	317	[1]	332	[1]
Fair Value, Measurements, Recurring | Fixed Income Securities | U.S. Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	478	[1]	458	[1]
Fair Value, Measurements, Recurring | Fixed Income Securities | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	328	[1]	329	[1]
Fair Value, Measurements, Recurring | Fixed Income Securities | Debt securities, other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	20	[1]	23	[1]
Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	82	[1]	60	[1]
Fair Value, Measurements, Recurring | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	104	[1]	141	[1]
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	2,365		2,100
Total liabilities	19		10
Fair Value, Measurements, Recurring | Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	54		44
Derivative Liabilities	19		10
Fair Value, Measurements, Recurring | Level 1 | Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0		0
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring | Level 1 | Equity Securities | Large cap | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	1,933	[1]	1,718	[1]
Fair Value, Measurements, Recurring | Level 1 | Equity Securities | Large cap | Non United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	11	[1]	10	[1]
Fair Value, Measurements, Recurring | Level 1 | Equity Securities | Equity securities, other | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	59	[1]	51	[1]
Fair Value, Measurements, Recurring | Level 1 | Fixed Income Securities | Corporate Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 1 | Fixed Income Securities | U.S. Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	308	[1]	277	[1]
Fair Value, Measurements, Recurring | Level 1 | Fixed Income Securities | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 1 | Fixed Income Securities | Debt securities, other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 1 | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	2,122		1,999
Total liabilities	913		983
Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	1,007		828
Derivative Liabilities	737		714
Fair Value, Measurements, Recurring | Level 2 | Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	94		105
Derivative Liabilities	176		269
Fair Value, Measurements, Recurring | Level 2 | Equity Securities | Large cap | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 2 | Equity Securities | Large cap | Non United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 2 | Equity Securities | Equity securities, other | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income Securities | Corporate Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	317	[1]	332	[1]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income Securities | U.S. Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	170	[1]	181	[1]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income Securities | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	328	[1]	329	[1]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income Securities | Debt securities, other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	20	[1]	23	[1]
Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	82	[1]	60	[1]
Fair Value, Measurements, Recurring | Level 2 | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	104	[1]	141	[1]
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	117		93
Total liabilities	178		164
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	117		93
Derivative Liabilities	178		164
Fair Value, Measurements, Recurring | Level 3 | Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0		0
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring | Level 3 | Equity Securities | Large cap | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Equity Securities | Large cap | Non United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Equity Securities | Equity securities, other | United States
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income Securities | Corporate Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income Securities | U.S. Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income Securities | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income Securities | Debt securities, other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	$ 0	[1]	$ 0	[1]

[1] Includes investments held in the nuclear decommissioning and rabbi trusts.

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Derivatives and Hedge Accounting Activities (Tables)

3 Months Ended

Mar. 31, 2012

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Volumes of Derivative Activity

The following table presents the volume of Dominion’s derivative activity as of March 31, 2012. 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 transactions, 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)	315		74
Basis(1)	861		484
Electricity (MWh):
Fixed price(1)	21,953,642		21,718,420
FTRs	21,805,241		810,816
Capacity (MW)	63,825		272,968
Liquids (gallons)(2)	137,508,000		221,214,000
Interest rate	$	2,000,000,000	$	1,940,000,000

(1) Includes options.

(2) Includes NGLs and oil.

Cash Flow Hedges Included Accumulated Other Comprehensive Income (Loss)

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion’s Consolidated Balance Sheet at March 31, 2012:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	(30	)	$	(16	)	33 months
Electricity	243			102			45 months
NGLs	(64		)	(27		)	33 months
Other	6			2			38 months
Interest rate	(97		)	(12		)	369 months
Total	$	58		$	49

Fair Value of Derivatives

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)
March 31, 2012
ASSETS
Current Assets
Commodity	$	312	$	472	$	784
Interest rate	38		—		38
Total current derivative assets	350		472		822
Noncurrent Assets
Commodity	295		99		394
Interest rate	56		—		56
Total noncurrent derivative assets(1)	351		99		450
Total derivative assets	$	701	$	571	$	1,272
LIABILITIES
Current Liabilities
Commodity	$	206	$	492	$	698
Interest rate	158		15		173
Total current derivative liabilities	364		507		871
Noncurrent Liabilities
Commodity	151		85		236
Interest rate	—		3		3
Total noncurrent derivative liabilities(2)	151		88		239
Total derivative liabilities	$	515	$	595	$	1,110
December 31, 2011
ASSETS
Current Assets
Commodity	$	176	$	495	$	671
Interest rate	34		—		34
Total current derivative assets	210		495		705
Noncurrent Assets
Commodity	198		96		294
Interest rate	71		—		71
Total noncurrent derivative assets(1)	269		96		365
Total derivative assets	$	479	$	591	$	1,070
LIABILITIES
Current Liabilities
Commodity	$	162	$	530	$	692
Interest rate	222		37		259
Total current derivative liabilities	384		567		951
Noncurrent Liabilities
Commodity	118		78		196
Interest rate	—		10		10
Total noncurrent derivative liabilities(2)	118		88		206
Total derivative liabilities	$	502	$	655	$	1,157

(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.

Gains and Losses on Derivatives in Cash Flow Hedging Relationships

The following tables present the gains and losses on Dominion's derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:

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 March 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	64
Purchased gas				(30		)
Electric fuel and other energy-related purchases				(7		)
Total commodity	$	176		27			$	(1	)
Interest rate(3)	32			1			27
Total	$	208		$	28		$	26
Three Months Ended March 31, 2011
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	28
Purchased gas				(48		)
Electric fuel and other energy-related purchases				1
Purchased electric capacity				1
Total commodity	$	(142	)	(18		)	$	(5	)
Interest rate(3)	(1		)	—			(1		)
Total	$	(143	)	$	(18	)	$	(6	)

(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.

Schedule of Derivatives not Designated as Hedging Instruments

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended March 31,
Derivatives not designated as hedging instruments	2012			2011
(millions)
Derivative Type and Location of Gains (Losses)
Commodity
Operating revenue	$	69		$	19
Purchased gas	(10		)	(11		)
Electric fuel and other energy-related purchases	(27		)	16
Interest rate(2)	(2		)	—
Total	$	30		$	24

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

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2012

Fair Value Disclosures [Abstract]

Fair Value, Option, Quantitative Disclosures

The following table presents Dominion's quantitative information about Level 3 fair value measurements. Included are descriptions of the valuation techniques, the significant unobservable inputs, and the range of market price, price correlation and price volatility inputs used in the fair value measurements at March 31, 2012 for each category of transaction and commodity type. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility and correlations.

	Fair Value (millions)		Valuation Technique(s)	Unobservable Input		Range	Weighted Average(1)
At March 31, 2012
Assets:
Physical and Financial Forwards and Futures:
Natural Gas(2)	$	31	Discounted Cash Flow	Market Price (per Dth)	(3)	(1) - 6	3
Electricity	69		Discounted Cash Flow	Market Price (per MWh)	(3)	21 - 61	43
FTRs	1		Discounted Cash Flow	Market Price (per MWh)	(3)	(3) - 3	—
Capacity	9		Discounted Cash Flow	Market Price (per MW)	(3)	95-120	101
Liquids	1		Discounted Cash Flow	Market Price (per Gal)	(3)	1 - 2	1
Physical and Financial Options:
Natural Gas	6		Option Model	Market Price (per Dth)	(3)	2 - 5	4
				Price Volatility	(4)	23% - 60%	30	%
				Price Correlation	(5)	100% - 100%	100	%
Total assets	$	117
Liabilities:
Physical and Financial Forwards and Futures:
Natural Gas(2)	$	21	Discounted Cash Flow	Market Price (per Dth)	(3)	(1) - 6	3
Electricity	17		Discounted Cash Flow	Market Price (per MWh)	(3)	12 - 61	41
FTRs	18		Discounted Cash Flow	Market Price (per MWh)	(3)	(6) - 5	—
Liquids	108		Discounted Cash Flow	Market Price (per Gal)	(3)	1 - 3	2
Physical and Financial Options:
Natural Gas(2)	14		Option Model	Market Price (per Dth)	(3)	(1) - 5	2
				Price Volatility	(4)	23% - 59%	36	%
				Price Correlation	(5)	70% - 100%	90	%
Total liabilities	$	178

(1) Averages weighted by volume.

(2) Includes basis.

(3) Represents market prices beyond defined terms for Levels 1 & 2.

(4) Represents volatilities unrepresented in published markets.

(5) Represents intra-price correlations for which markets do not exist.

Fair Value, by Balance Sheet Grouping

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)
At March 31, 2012
Assets:
Derivatives:
Commodity	$	54	$	1,007	$	117	$	1,178
Interest rate	—		94		—		94
Investments(1):
Equity securities:
U.S.:
Large cap	1,933		—		—		1,933
Other	59		—		—		59
Non-U.S.:
Large cap	11		—		—		11
Fixed income:
Corporate debt instruments	—		317		—		317
U.S. Treasury securities and agency debentures	308		170		—		478
State and municipal	—		328		—		328
Other	—		20		—		20
Cash equivalents and other	—		82		—		82
Restricted cash equivalents	—		104		—		104
Total assets	$	2,365	$	2,122	$	117	$	4,604
Liabilities:
Derivatives:
Commodity	$	19	$	737	$	178	$	934
Interest rate	—		176		—		176
Total liabilities	$	19	$	913	$	178	$	1,110
At December 31, 2011
Assets:
Derivatives:
Commodity	$	44	$	828	$	93	$	965
Interest rate	—		105		—		105
Investments(1):
Equity securities:
U.S.:
Large cap	1,718		—		—		1,718
Other	51		—		—		51
Non-U.S.:
Large cap	10		—		—		10
Fixed income:
Corporate debt instruments	—		332		—		332
U.S. Treasury securities and agency debentures	277		181		—		458
State and municipal	—		329		—		329
Other	—		23		—		23
Cash equivalents and other	—		60		—		60
Restricted cash equivalents	—		141		—		141
Total assets	$	2,100	$	1,999	$	93	$	4,192
Liabilities:
Derivatives:
Commodity	$	10	$	714	$	164	$	888
Interest rate	—		269		—		269
Total liabilities	$	10	$	983	$	164	$	1,157

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

Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation

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 March 31,
	2012			2011
(millions)
Beginning balance	$	(71	)	$	(50	)
Total realized and unrealized gains (losses):
Included in earnings	(35		)	14
Included in other comprehensive income (loss)	5			(94		)
Included in regulatory assets/liabilities	11			(21		)
Settlements	30			(16		)
Transfers out of Level 3	(1		)	4
Ending balance	$	(61	)	$	(163	)
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	$	1		$	4

Fair Value, Unobservable Inputs, Gain (Loss) Included In Earnings

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			Total
(millions)
Three Months Ended March 31, 2012
Total gains (losses) included in earnings	$	(9	)	$	(26	)	$	(35	)
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	1			—			1
Three Months Ended March 31, 2011
Total gains (losses) included in earnings	$	(2	)	$	16		$	14
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

Cost and Fair Value of Financial Instruments Disclosure

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:

	March 31, 2012				December 31, 2011
	Carrying Amount		Estimated Fair Value(1)		Carrying Amount			Estimated Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	16,695	$	19,256	$	16,264	18,936	$	18,936
Long-term debt, VIE(3)	882		889		890		892	892
Junior subordinated notes payable to affiliates	268		272		268		268	268
Enhanced junior subordinated notes	1,365		1,437		1,451		1,518	1,518
Subsidiary preferred stock(4)	257		259		257		256	256
Virginia Power
Long-term debt, including securities due within one year(2)	$	7,308	$	8,628	$	6,862		$	8,281
Preferred stock(4)	257		259		257			256

(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. All fair value measurements are classified as Level 2. 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 March 31, 2012 and December 31, 2011, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $93 million and $105 million, respectively.

(3) Includes amounts which represent the unamortized premium.

(4) Includes deferred issuance expenses of $2 million at March 31, 2012 and December 31, 2011.

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Regulatory Matters (Narrative) (Details) (USD $)	1 Months Ended	3 Months Ended			11 Months Ended	3 Months Ended
	Mar. 31, 2010 Virginia Electric and Power Company [Member]	Mar. 31, 2012 Virginia Electric and Power Company [Member]	Mar. 31, 2012 Virginia Electric and Power Company [Member] Virginia Regulation Base Roe	Dec. 31, 2011 Virginia Electric and Power Company [Member] Virginia Regulation Base Roe	Nov. 30, 2011 Virginia Electric and Power Company [Member] Virginia Regulation Base Roe	Mar. 31, 2012 Virginia Electric and Power Company [Member] Virginia Regulation Rider R and S	Mar. 31, 2012 Virginia Electric and Power Company [Member] Virginia Regulation Rider R	Mar. 31, 2012 Virginia Electric and Power Company [Member] Virginia Regulation Rider S	Mar. 31, 2012 Virginia Electric and Power Company [Member] Virginia Regulation Rider B MW	Mar. 31, 2012 Virginia Electric and Power Company [Member] North Carolina Regulation	Mar. 31, 2012 East Ohio [Member] Ohio Regulation [Member]
Authorized ROE		11.40%				11.40%			12.40%
Incentive For Four Electric Transmission Enhancement Projects		1.50%
Incentive For Seven Electric Transmission Enhancement Projects		1.25%
Costs Claimed To Be Unjust And Excluded From Transmission Formula Rate	$ 223,000,000
Potential Settlement Required Annual Payment For 10 Years		250,000
Liability Due To Change In Estimate Of Future Billing Adjustments		36,000,000
New Authorized ROE			10.90%	10.90%	10.90%
Basis Points Enhancement To ROE						1.00%			2.00%
Basis Points Performance Incentive As Provided For By Regulation Act			0.50%
ROE Established In Virginia Settlement Approval Order					11.90%
Revenue Requirement Under Riders							74,000,000	226,000,000
Pre Commercial Operation Period Revenue Requirement Under Riders								52,000,000
Commercial Operation Period Revenue Requirement Under Riders								174,000,000
Rider B Renewable Generation Capacity									150
Approved Rider Revenue Requirement									6,000,000
Number Of Years Enhancement Basis Points Are Added To Rider									5 years
Proposed Increase Decrease In Base Revenue										64,000,000
Proposed Increase In Net Revenue										37,000,000
Proposed PIR Total Gross Plant Investment											73,000,000
Cumulative Gross Plant Investment											362,000,000
Proposed Revenue Requirement											$ 47,000,000

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Fair Value Measurements (Net Change in the Assets and Liabilities Measured at Fair Value on a Recurring Basis and Included in the Level 3 Fair Value Category) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Total realized and unrealized gains (losses):
Included in earnings	$ (35)	$ 14
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	1	4
Fair Value, Measurements, Recurring
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	(71)	(50)
Total realized and unrealized gains (losses):
Included in earnings	(35)	14
Included in other comprehensive income (loss)	5	(94)
Included in regulatory assets/liabilities	11	(21)
Settlements	30	(16)
Transfers out of Level 3	(1)	4
Ending balance	(61)	(163)
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	$ 1	$ 4

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Investments (Tables)

3 Months Ended

Mar. 31, 2012

Investments, Debt and Equity Securities [Abstract]

Available-For-Sale Securities

Dominion’s decommissioning trust funds are summarized below.

	Amortized Cost		Total  Unrealized Gains(1)		Total  Unrealized Losses (1)				Fair Value
(millions)
March 31, 2012
Marketable equity securities
U.S.:
Large Cap	$	1,178	$	724	$	—			$	1,902
Other	38		15		—				53
Marketable debt securities:
Corporate bonds	296		22		(1		)		317
U.S. Treasury securities and agency debentures	459		18		(1		)		476
State and municipal	267		21		—				288
Other	19		1		—				20
Cost method investments	117		—		—				117
Cash equivalents and other(2)	58		—		—				58
Total	$	2,432	$	801	$	(2	)	(3)	$	3,231
December 31, 2011
Marketable equity securities:
U.S.:
Large Cap	$	1,152	$	537	$	—			$	1,689
Other	36		10		—				46
Marketable debt securities:
Corporate bonds	314		19		(1		)		332
U.S. Treasury securities and agency debentures	437		20		(1		)		456
State and municipal	264		24		—				288
Other	23		1		—				24
Cost method investments	118		—		—				118
Cash equivalents and other(2)	46		—		—				46
Total	$	2,390	$	611	$	(2	)	(3)	$	2,999

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

(2) Includes pending purchases of securities of $20 million and $11 million at March 31, 2012 and December 31, 2011, respectively.

(3) The fair value of securities in an unrealized loss position was $192 million and $164 million at March 31, 2012 and December 31, 2011, respectively.

Investments Classified by Contractual Maturity Date

The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at March 31, 2012 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	62
Due after one year through five years	324
Due after five years through ten years	338
Due after ten years	377
Total	$	1,101

Marketable Securities

Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended March 31,
	2012		2011
(millions)
Proceeds from sales	$	415	$	502
Realized gains(1)	28		14
Realized losses(1)	4		8

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

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Significant Financing Transactions (Tables)

3 Months Ended

Mar. 31, 2012

Securities Financing Transactions Disclosures [Abstract]

Schedule of Line of Credit Facilities

At March 31, 2012, Dominion’s commercial paper and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:

	Facility Limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	3,000	$	1,057	$	—	$	1,943
Joint revolving credit facility(2)	500		—		36		464
Total	$	3,500	$	1,057	$	36	$	2,407

(1) This credit facility has a maturity date of September 2016, and 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.

(2) This credit facility has a maturity date of September 2016, and can be used to support bank borrowings, commercial paper and letter of credit issuances.

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Nature of Operations

3 Months Ended

Mar. 31, 2012

Nature of Operations [Abstract]

Nature of Operations

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.

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Schedule Of Subsidiary Guarantees

At March 31, 2012, Dominion had issued the following subsidiary guarantees:

	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	363	$	363
Commodity transactions(3)	3,360		273
Nuclear obligations(4)	231		62
Other(5)	481		44
Total	$	4,435	$	742

(1) Represents the estimated portion of the guarantee's stated limit that is utilized as of March 31, 2012 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, including subsidiaries of Virginia Power and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and 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 limits.

(4) 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.

(5) 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.

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Earnings Per Share (Calculation of Our Basic and Diluted EPS) (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Earnings Per Share [Abstract]
Net Income (Loss) Attributable to Parent	$ 494		$ 479
Average shares of common stock outstanding - Basic	570.5		579.8
Net effect of potentially dilutive securities	1.4	[1]	0.7	[1]
Average shares of common stock outstanding - Diluted	571.9		580.5
Earnings Per Common Share - Basic	$ 0.87		$ 0.83
Earnings Per Common Share - Diluted	$ 0.86		$ 0.82

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

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Investments (Marketable Equity and Debt Securities and Cash Equivalents (Classified as Available-for-sale) and Cost Method Investments in Decommissioning Trust Funds) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012		Dec. 31, 2011
Amortized Cost, Total	$ 2,432		$ 2,390
Total Unrealized Gains	801	[1]	611	[1]
Total Unrealized Losses	(2)	[1],[2]	(2)	[1],[2]
Fair Value	3,231		2,999	[3]
Net assets related to pending sales and purchases of securities	20		11
Fair Value of securities in an unrealized loss position	192		164
Cost-method Investments [Member]
Amortized Cost, Other Investments	117		118
Total Unrealized Gains	0		0
Total Unrealized Losses	0		0
Fair Value	117		118
Cash Equivalents and Other Investment [Member]
Amortized Cost, Other Investments	58	[4]	46	[4]
Total Unrealized Gains	0		0
Total Unrealized Losses	0		0
Fair Value	58	[4]	46	[4]
Equity Securities [Member] | Large Cap | United States
Amortized Cost, Marketable Securities	1,178		1,152
Total Unrealized Gains	724	[1]	537	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	1,902		1,689
Equity Securities [Member] | Other Market [Member] | United States
Amortized Cost, Marketable Securities	38		36
Total Unrealized Gains	15	[1]	10	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	53		46
Corporate bonds
Amortized Cost, Marketable Securities	296		314
Total Unrealized Gains	22	[1]	19	[1]
Total Unrealized Losses	(1)	[1]	(1)	[1]
Fair Value	317		332
U.S. Treasury Securities and Agency Debentures
Amortized Cost, Marketable Securities	459		437
Total Unrealized Gains	18	[1]	20	[1]
Total Unrealized Losses	(1)	[1]	(1)	[1]
Fair Value	476		456
State and Municipal
Amortized Cost, Marketable Securities	267		264
Total Unrealized Gains	21	[1]	24	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	288		288
Other Debt Securities
Amortized Cost, Marketable Securities	19		23
Total Unrealized Gains	1	[1]	1	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	$ 20		$ 24

[1] Included in AOCI and the decommissioning trust regulatory liability.

[2] The fair value of securities in an unrealized loss position was $192 million and $164 million at March 31, 2012 and December 31, 2011, respectively.

[3] Dominion’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

[4] Includes pending purchases of securities of $20 million and $11 million at March 31, 2012 and December 31, 2011, respectively.

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Consolidated Statements of Income (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating Revenue	$ 3,492	$ 4,057
Operating Expenses
Electric fuel and other energy-related purchases	948	1,049
Purchased electric capacity	113	119
Purchased gas	412	642
Other operations and maintenance	647	861
Depreciation, depletion and amortization	287	262
Other taxes	170	161
Total operating expenses	2,577	3,094
Income from operations	915	963
Other income	74	57
Interest and related charges	228	227
Income from operations including noncontrolling interests before income tax expense	761	793
Income tax expense	260	310
Net Income Including Noncontrolling Interest	501	483
Noncontrolling Interests	7	4
Net Income attributable to Dominion	494	479
Amounts Attributable to Dominion:
Earnings Per Common Share - Basic	$ 0.87	$ 0.83
Earnings Per Common Share - Diluted	$ 0.86	$ 0.82
Dividends declared per common share	$ 0.5275	$ 0.4925
Virginia Electric and Power Company [Member]
Operating Revenue	1,754	1,757
Operating Expenses
Electric fuel and other energy-related purchases	614	593
Purchased electric capacity	113	118
Affiliated suppliers	83	73
Other	223	229
Depreciation, depletion and amortization	188	174
Other taxes	65	59
Total operating expenses	1,286	1,246
Income from operations	468	511
Other income	23	29
Interest and related charges	100	92
Income from operations including noncontrolling interests before income tax expense	391	448
Income tax expense	148	170
Net Income attributable to Dominion	243	278
Amounts Attributable to Dominion:
Preferred dividends	4	4
Balance available for common stock	$ 239	$ 274

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Fair Value Measurements (Gains and Losses Included in Earnings in the Level 3 Fair Value Category) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Total gains (losses) included in earnings	$ (35)	$ 14
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	1	4
Operating revenue [Member]
Total gains (losses) included in earnings	(9)	(2)
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	1	4
Electric fuel and other energy-related purchases
Total gains (losses) included in earnings	(26)	16
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	$ 0	$ 0

XML

Consolidated Balance Sheets (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Customer receivables, allowance for doubtful accounts	$ 29	$ 29
Other receivables, allowance for doubtful accounts	5	8
Common stock, shares authorized	1,000,000,000	1,000,000,000
Common stock, shares outstanding	571,000,000	570,000,000
Virginia Electric and Power Company [Member]
Customer receivables, allowance for doubtful accounts	11	11
Other receivables, allowance for doubtful accounts	$ 4	$ 7
Common stock, shares authorized	500,000	500,000
Common stock, shares outstanding	274,723	274,723

XML

Significant Financing Transactions - (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Details) (USD $)	Mar. 31, 2012
Facility Limit	$ 3,500,000,000
Outstanding Commercial Paper	1,057,000,000
Outstanding Letters of Credit	36,000,000
Facility Capacity Available	2,407,000,000
Three Year Joint Revolving Credit Facility [Member}
Facility Limit	500,000,000	[1]
Outstanding Commercial Paper	0	[1]
Outstanding Letters of Credit	36,000,000	[1]
Facility Capacity Available	464,000,000	[1]
Credit Facility 1.5 Billion | Three Year Joint Revolving Credit Facility [Member}
Facility Limit	3,000,000,000	[2]
Outstanding Commercial Paper	1,057,000,000	[2]
Outstanding Letters of Credit	0	[2]
Facility Capacity Available	1,943,000,000	[2]
Credit Facility, to support letters of credit	$ 1,500,000,000

[1] This credit facility has a maturity date of September 2016, and can be used to support bank borrowings, commercial paper and letter of credit issuances.

[2] This credit facility has a maturity date of September 2016, and 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.

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Operating Segments (Tables)

3 Months Ended

Mar. 31, 2012

Segment Reporting [Abstract]

Segment Reporting Disclosure Other Information

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 and storage	X
	LNG import and storage	X
	Producer services	X

Schedule of Segment Reporting Information, by Segment

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 March 31,
2012
Total revenue from external customers	$	930	$	1,675	$	616	$	39		$	232		$	3,492
Intersegment revenue	63		76		200		149			(488		)	—
Total operating revenue	993		1,751		816		188			(256		)	3,492
Net income (loss) attributable to Dominion	166		223		149		(44		)	—			494
2011
Total revenue from external customers	$	1,051	$	1,863	$	834	$	36		$	273		$	4,057
Intersegment revenue	95		70		208		143			(516		)	—
Total operating revenue	1,146		1,933		1,042		179			(243		)	4,057
Net income (loss) attributable to Dominion	149		298		169		(137		)	—			479

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Employee Benefit Plans (Net Periodic Benefit Cost) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Pension Benefits [Member]
Service cost	$ 29	$ 27
Interest cost	67	64
Expected return on plan assets	(108)	(110)
Amortization of prior service cost (credit)	1	1
Amortization of net loss	33	24
Net periodic benefit cost	22	6
Other Postretirement Benefits [Member]
Service cost	11	12
Interest cost	20	23
Expected return on plan assets	(21)	(20)
Amortization of prior service cost (credit)	(3)	(3)
Amortization of net loss	2	3
Net periodic benefit cost	$ 9	$ 15

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Employee Benefit Plans

3 Months Ended

Mar. 31, 2012

Compensation and Retirement Disclosure [Abstract]

Employee Benefit Plans

Employee Benefit Plans

The components of Dominion's provision for net periodic benefit cost were as follows:

	Pension Benefits						Other Postretirement Benefits
	2012			2011			2012			2011
(millions)
Three Months Ended March 31,
Service cost	$	29		$	27		$	11		$	12
Interest cost	67			64			20			23
Expected return on plan assets	(108		)	(110		)	(21		)	(20		)
Amortization of prior service cost (credit)	1			1			(3		)	(3		)
Amortization of net loss	33			24			2			3
Net periodic benefit cost	$	22		$	6		$	9		$	15

Employer Contributions

During the three months ended March 31, 2012, Dominion made no contributions to its defined benefit pension plans or OPEB plans. Dominion expects to contribute approximately $16 million to its OPEB plans through Voluntary Employees' Beneficiary Associations during the remainder of 2012.

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Operating Revenue (Operating Revenue) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Electric sales:
Regulated	$ 1,724	$ 1,730
Nonregulated	738	941
Gas sales:
Regulated	99	139
Nonregulated	398	602
Gas transportation and storage	405	538
Other	128	107
Total operating revenue	$ 3,492	$ 4,057

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2012

Accounting Policies [Abstract]

General

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 March 31, 2012 and their results of operations and cash flows for the three months ended March 31, 2012 and 2011. 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 and those VIEs where Dominion has been determined to be the primary beneficiary.

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 2011 Consolidated Financial Statements and Notes have been reclassified to conform to the 2012 presentation for comparative purposes. The reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows.

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

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Consolidated Statements of Cash Flows (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Operating Activities
Net income including noncontrolling interests	$ 501		$ 483
Net Income	494		479
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)	353		318
Deferred income taxes and investment tax credits	269		227
Rate refunds	(55)		(29)
Other adjustments	(72)		(17)
Changes in:
Accounts receivable	327		292
Inventories	99		119
Deferred fuel and purchased gas costs, net	162		(50)
Prepayments	37		54
Accounts payable	(275)		(299)
Accrued interest, payroll and taxes	89		(129)
Margin deposit assets and liabilities	97		(120)
Other operating assets and liabilities	91		63
Net cash provided by operating activities	1,623		912
Investing Activities
Plant construction and other property additions	(981)		(806)
Proceeds from sale of securities	415		502
Purchases of securities	(420)		(522)
Restricted cash equivalents	37		56
Other	3		18
Net cash used in investing activities	(946)		(752)
Financing Activities
Repayment of short-term debt, net	(757)		(538)
Issuance and remarketing of long-term debt	450		1,060
Repayment and repurchase of long-term debt	(104)		(2)
Issuance of common stock	69		17
Repurchase of common stock	0		(274)
Common dividend payments	(301)		(285)
Subsidiary preferred dividend payments	(4)		(4)
Other	1		(8)
Net cash used in financing activities	(646)		(34)
Increase (decrease) in cash and cash equivalents	31		126
Cash and cash equivalents at beginning of period	102	[1]	62
Cash and cash equivalents at end of period	133		188
Significant noncash investing activities:
Accrued capital expenditures	298		167
Virginia Electric and Power Company [Member]
Operating Activities
Net Income	243		278
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)	222		205
Deferred income taxes and investment tax credits	85		150
Rate refunds	(55)		(29)
Other adjustments	(20)		(32)
Changes in:
Accounts receivable	125		127
Affiliated accounts receivable and payable	(15)		(31)
Inventories	20		(42)
Deferred fuel and purchased gas costs, net	156		(32)
Accounts payable	(59)		(69)
Accrued interest, payroll and taxes	137		25
Other operating assets and liabilities	67		(26)
Net cash provided by operating activities	906		524
Investing Activities
Plant construction and other property additions	(483)		(408)
Purchases of nuclear fuel	(67)		(49)
Proceeds from sale of securities	191		343
Purchases of securities	(193)		(362)
Restricted cash equivalents	3		56
Other	(9)		9
Net cash used in investing activities	(558)		(411)
Financing Activities
Repayment of short-term debt, net	(639)		(18)
Issuance of affiliated current borrowings, net	0		(44)
Issuance and remarketing of long-term debt	450		160
Common dividend payments	(149)		(130)
Subsidiary preferred dividend payments	(4)		(4)
Other	(7)		(2)
Net cash used in financing activities	(349)		(38)
Increase (decrease) in cash and cash equivalents	(1)		75
Cash and cash equivalents at beginning of period	29	[2]	5
Cash and cash equivalents at end of period	28		80
Significant noncash investing activities:
Accrued capital expenditures	$ 208		$ 121

[1] Dominion’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

[2] Virginia Power’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

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Consolidated Statements of Comprehensive Income (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net income including noncontrolling interests	$ 501	$ 483
Net income	494	479
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	128	(85)
Changes in unrealized net gains on investment securities, net of tax	85	38
Changes in net unrecognized pension and other postretirement benefit costs, net of tax	0	25
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	(16)	13
Net realized gains on investment securities, net of tax	(10)	(2)
Net pension and other postretirement benefit costs, net of tax	12	14
Total other comprehensive income	199	3
Comprehensive income including noncontrolling interests	700	486
Comprehensive income attributable to noncontrolling interests	7	4
Comprehensive income	693	482
Virginia Electric and Power Company [Member]
Net income	243	278
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	(1)	0
Changes in unrealized net gains on investment securities, net of tax	9	3
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	1	(1)
Net realized gains on investment securities, net of tax	(1)	0
Total other comprehensive income	8	2
Comprehensive income	$ 251	$ 280

XML

Variable Interest Entities

3 Months Ended

Mar. 31, 2012

Variable Interest Entities [Abstract]

Variable Interest Entities

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, 2011, 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 summer generation capacity of approximately 870 MW. 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 entities 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 $1.2 billion as of March 31, 2012. Virginia Power paid $55 million and $53 million for electric capacity and $19 million and $39 million for electric energy to these entities in the three months ended March 31, 2012 and 2011, respectively.

Virginia Power purchased shared services from DRS, an affiliated VIE, of approximately $96 million and $93 million for the three months ended March 31, 2012 and 2011, 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.

See 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, 2011 for additional information about consolidated VIEs.

XML

Document and Entity Information	3 Months Ended
	Mar. 31, 2012
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
Trading Symbol	D
Entity Registrant Name	DOMINION RESOURCES INC /VA/
Entity Central Index Key	0000715957
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	571,498,534
Virginia Electric and Power Company [Member]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
Trading Symbol	VEL - PE
Entity Registrant Name	VIRGINIA ELECTRIC & POWER CO
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding	274,723

XML

Significant Financing Transactions

3 Months Ended

Mar. 31, 2012

Securities Financing Transactions Disclosures [Abstract]

Significant Financing Transactions

Significant Financing Transactions

Credit Facilities and Short-term Debt

Dominion and Virginia Power use short-term debt to fund working capital requirements and as a bridge to long-term debt financings. 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. Collateral requirements are impacted by commodity prices, hedging levels, Dominion’s credit ratings and the credit quality of its counterparties.

At March 31, 2012, Dominion’s commercial paper and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:

	Facility Limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	3,000	$	1,057	$	—	$	1,943
Joint revolving credit facility(2)	500		—		36		464
Total	$	3,500	$	1,057	$	36	$	2,407

(1) This credit facility has a maturity date of September 2016, and 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.

(2) This credit facility has a maturity date of September 2016, and can be used to support bank borrowings, commercial paper and letter of credit issuances.

Virginia Power’s short-term financing is supported by two joint revolving credit facilities with Dominion. These credit facilities are being used for working capital, as support for the combined commercial paper programs of Dominion and Virginia Power and for other general corporate purposes.

At March 31, 2012, Virginia Power’s share of commercial paper and letters of credit outstanding, as well as its capacity available under its joint credit facilities with Dominion were as follows:

	Facility Sub-limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	1,000	$	255	$	—	$	745
Joint revolving credit facility(2)	250		—		15		235
Total	$	1,250	$	255	$	15	$	980

(1) This credit facility has a maturity date of September 2016, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (or the sub-limit, whichever is less) of letters of credit. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.

(2) This credit facility has a maturity date of September 2016, and can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.

In addition to the credit facility commitments mentioned above, Virginia Power also has a $120 million credit facility with a maturity date of September 2016. This facility supports certain tax-exempt financings of Virginia Power.

Long-term Debt

In January 2012, Virginia Power issued $450 million of 2.95% senior notes that mature in 2022.

Convertible Securities

At March 31, 2012, Dominion had $137 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 March 31, 2012, the conversion rate has been adjusted, primarily due to individual dividend payments above the level paid at issuance, to 29.0360 shares of common stock per $1,000 principal amount of senior notes, which represents a conversion price of $34.44.

The senior notes are eligible for conversion during any calendar quarter when the closing price of Dominion’s common stock was equal to or higher than 120% of the conversion price for at least 20 out of the last 30 consecutive trading days of the preceding quarter. During the three months ended March 31, 2012, the senior notes were eligible for conversion and approximately $6 million of the notes were converted by holders. The senior notes are eligible for conversion during the second quarter of 2012.

Enhanced Junior Subordinated Notes

In February 2012, Dominion launched a tender offer to purchase up to $150 million of the September 2006 hybrids, which amount could be increased or decreased at Dominion's sole discretion.  In the first quarter of 2012, Dominion purchased and canceled approximately $86 million of the September 2006 hybrids primarily as a result of this tender offer, which expired on March 23, 2012. All purchases were conducted in compliance with the RCC. From time to time, Dominion may reduce its outstanding debt and level of interest expense through redemption of debt securities prior to maturity and repurchases in the open market, in privately negotiated transactions, through additional tender offers or otherwise.

XML

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net deferred gains (losses) on derivative-hedging activities, tax	$ (80)	$ 58
Changes in unrealized net gains (losses) on investment securities, tax	(56)	(25)
Changes in net unrecognized pension and other postretirement benefit costs, tax	0	(15)
Net derivative (gains) losses-hedging activities, tax	12	(5)
Net realized gains on investment securities, tax	6	2
Net pension and other postretirement benefit costs, tax	(9)	(2)
Virginia Electric and Power Company [Member]
Net deferred gains (losses) on derivative-hedging activities, tax	0	0
Changes in unrealized net gains (losses) on investment securities, tax	(5)	(2)
Net derivative (gains) losses-hedging activities, tax	(1)	0
Net realized gains on investment securities, tax	$ 1	$ 0

XML

Earnings Per Share

3 Months Ended

Mar. 31, 2012

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per Share

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

	Three Months Ended March 31,
	2012		2011
(millions, except EPS)
Net income attributable to Dominion	$	494	$	479
Average shares of common stock outstanding – Basic	570.5		579.8
Net effect of potentially dilutive securities(1)	1.4		0.7
Average shares of common stock outstanding – Diluted	571.9		580.5
Earnings Per Common Share – Basic	$	0.87	$	0.83
Earnings Per Common Share – Diluted	$	0.86	$	0.82

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

There were no potentially dilutive securities excluded from the calculation of diluted EPS for the three months ended March 31, 2012 and 2011.

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Income Taxes

3 Months Ended

Mar. 31, 2012

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

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
Three Months Ended March 31,	2012		2011		2012		2011
U.S. statutory rate	35.0	%	35.0	%	35.0	%	35.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.8		3.7		3.9		3.9
Valuation allowances	(2.7	)	0.8		—		—
AFUDC - equity	(0.7	)	(0.7	)	(0.9	)	(1.1	)
Other, net	(1.3	)	0.3		(0.2	)	0.2
Effective tax rate	34.1	%	39.1	%	37.8	%	38.0	%

Dominion's effective tax rate in 2012 reflects a $20 million reduction of a valuation allowance related to certain state operating loss carryforwards. As disclosed in Note 16 to the Consolidated Financial Statements in its Annual Report on Form 10-K for the year ended December 31, 2011, Dominion expects to purchase Fairless in 2013. Dominion currently operates the facility under a lease and, as a result of a 2012 contract modification, the exercise price of Dominion's option to purchase Fairless is fixed at approximately $923 million. After considering the results of Fairless' operations in recent years and a forecast of future operating results reflecting the planned purchase of the facility, Dominion has concluded that it is more likely than not that the tax benefit of the operating losses will be realized. Significant assumptions include future commodity prices, in particular, those for electric energy produced by Fairless and those for natural gas, as compared to other fuels used for the generation of electricity, which will significantly influence the extent to which Fairless is dispatched by PJM. Realization of these tax benefits ultimately depends on whether or not the forecasted results are achieved. Dominion will continue to evaluate the likelihood of realizing these tax benefits on a quarterly basis.

As of March 31, 2012, there have been no material changes in Dominion's and Virginia Power's unrecognized tax benefits or possible changes that could reasonably be expected to occur during the next twelve months. See Note 6 to the Consolidated Financial Statements in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2011 for a discussion of these unrecognized tax benefits.

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Operating Segments

3 Months Ended

Mar. 31, 2012

Segment Reporting [Abstract]

Operating Segments

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 and storage	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.

In the three months ended March 31, 2012, Dominion reported an after-tax net benefit of $7 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments. In the three months ended March 31, 2011, Dominion reported after-tax net expenses of $62 million for specific items in the Corporate and Other segment, with $54 million of these net expenses attributable to its operating segments.

There were no material net benefit or expense items in the Corporate and Other segment in 2012.

The net expenses for specific items in 2011 primarily related to the impact of the following items:

• A $55 million ($39 million after-tax) impairment charge related to State Line, attributable to Dominion Generation; and

• A $32 million ($19 million after-tax) loss from the operations of Kewaunee, attributable to Dominion Generation.  Kewaunee's results of operations have been reflected in the Corporate and Other segment due to Dominion's decision in the first quarter of 2011 to pursue the sale of Kewaunee.

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 three months ended March 31, 2012, Virginia Power reported an after-tax benefit of $1 million for specific items attributable to its operating segments in the Corporate and Other segment. Virginia Power recorded no such amounts in its Corporate and Other segment during the three months ended March 31, 2011.

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 March 31,
2012
Total revenue from external customers	$	930	$	1,675	$	616	$	39		$	232		$	3,492
Intersegment revenue	63		76		200		149			(488		)	—
Total operating revenue	993		1,751		816		188			(256		)	3,492
Net income (loss) attributable to Dominion	166		223		149		(44		)	—			494
2011
Total revenue from external customers	$	1,051	$	1,863	$	834	$	36		$	273		$	4,057
Intersegment revenue	95		70		208		143			(516		)	—
Total operating revenue	1,146		1,933		1,042		179			(243		)	4,057
Net income (loss) attributable to Dominion	149		298		169		(137		)	—			479

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

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

	DVP		Dominion Generation		Corporate and Other		Consolidated Total
(millions)
Three Months Ended March 31,
2012
Operating revenue	$	459	$	1,295	$	—	$	1,754
Net income	107		133		3		243
2011
Operating revenue	$	453	$	1,304	$	—	$	1,757
Net income	113		165		—		278

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, and/or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. This estimated range is based on currently available information and involves elements of judgment and significant uncertainties. This estimated range of possible loss does not represent the Companies' maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on Dominion's or Virginia Power's financial position, liquidity or results of operations.

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.

Air

The CAA is a comprehensive program utilizing a broad range of regulatory tools to protect and preserve the nation's air quality. At a minimum, states are required to establish regulatory programs to address all requirements of the CAA. However, states may choose to develop regulatory programs that are more restrictive. Many of Dominion's and Virginia Power's facilities are subject to the CAA's permitting and other requirements.

On December 21, 2011, the EPA issued MATS for coal and oil-fired electric utility steam generating units. The rule establishes strict emission limits for mercury, particulate matter as a surrogate for toxic metals and hydrogen chloride as a surrogate for acid gases. The rule includes a limited use provision for oil-fired units with annual capacity factors under 8% that provides an exemption from emission limits, and allows compliance with operational work practice standards. Compliance will be required by Spring 2015, with certain limited exceptions. Other than impacts disclosed in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2011, the cost to comply with the rule is not expected to be material. Dominion continues to be governed by individual state mercury emission reduction regulations in Massachusetts and Illinois that are largely unaffected by this rule.

In July 2011, the EPA issued a final replacement rule for CAIR, called CSAPR, that requires 28 states to reduce power plant emissions that cross state lines. CSAPR establishes new SO₂ and NO_x emissions cap and trade programs that are completely independent of the current ARP. Specifically, CSAPR requires reductions in SO₂ and NO_x emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NO_x emissions caps, NO_x emissions caps during the ozone season (May 1 through September 30) and annual SO₂ emission caps with differing requirements for two groups of affected states.

With respect to Dominion's generation fleet, the cost to comply with the rule is not expected to be material. However, following numerous petitions by industry participants for review and motions for stay, the U.S. Court of Appeals for the D.C. Circuit issued a ruling in December 2011 to stay CSAPR pending judicial review. Also, in the fourth quarter of 2011, the EPA proposed technical revisions to CSAPR. Accordingly, future outcomes of litigation and/or final action to modify the rule could affect this assessment. While the stay of CSAPR is in effect, the EPA will continue to administer CAIR.

In February 2008, Dominion received a request for information pursuant to Section 114 of the CAA from the EPA. The request concerns historical operating changes and capital improvements undertaken at State Line and Kincaid. In April 2009, Dominion received a second request for information. Dominion provided information in response to both requests. Also in April 2009, Dominion received a Notice and Finding of Violations from the EPA claiming violations of the CAA New Source Review requirements, NSPS, the Title V permit program and the stations' respective State Implementation Plans. The Notice states that the EPA may issue an order requiring compliance with the relevant CAA provisions and may seek injunctive relief and/or civil penalties, all pursuant to the EPA's enforcement authority under the CAA.

Dominion believes that it complied with applicable laws and the EPA regulations and interpretations in effect at the time the work in question took place. The CAA authorizes maximum civil penalties of $25,000 to $37,500 per day, per violation at each generating unit, depending on the date of the alleged violation. In addition to any such penalties that may be awarded, an adverse outcome could require substantial capital expenditures or affect the timing of currently budgeted capital expenditures. Such expenditures could affect future results of operations, cash flows, and financial condition. Dominion is currently unable to make an estimate of the potential financial statement impacts related to these matters.

Water

The CWA is a comprehensive program requiring a broad range of regulatory tools including a permit program to authorize and regulate discharges to surface waters with strong enforcement mechanisms. Dominion and Virginia Power must comply with all aspects of the CWA programs at their operating facilities.

In October 2003, the EPA and the Massachusetts Department of Environmental Protection each issued new NPDES permits for Brayton Point. The new permits contained identical conditions that in effect require the installation of cooling towers to address concerns over the withdrawal and discharge of cooling water. Currently, Dominion is constructing the cooling towers and estimates the total cost to install these cooling towers at approximately $570 million, with remaining expenditures of approximately $65 million included in its planned capital expenditures through 2012.

In September 2010, Millstone's NPDES permit was reissued under the CWA. 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. Dominion is currently unable to make an estimate of the potential financial statement impacts related to this matter.

Solid and Hazardous Waste

The CERCLA, as amended, provides for immediate response and removal actions coordinated by the EPA in the event of threatened releases of hazardous substances into the environment and authorizes the U.S. government either to clean up sites at which hazardous substances have created actual or potential environmental hazards or to order persons responsible for the situation to do so. Under the CERCLA, as amended, generators and transporters of hazardous substances, as well as past and present owners and operators of contaminated sites, can be strictly, jointly and severally liable for the cost of cleanup. These potentially responsible parties can be ordered to perform a cleanup, be sued for costs associated with an EPA-directed cleanup, voluntarily settle with the U.S. government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight.

From time to time, Dominion or Virginia Power may be identified as a potentially responsible party to a Superfund site. The EPA (or a state) can either allow such a party to conduct and pay for a remedial investigation, feasibility study and remedial action or conduct the remedial investigation and action itself and then seek reimbursement from the potentially responsible parties. Each party can be held jointly, severally and strictly liable for the cleanup costs. These parties can also bring contribution actions against each other and seek reimbursement from their insurance companies. As a result, Dominion or Virginia Power may be responsible for the costs of remedial investigation and actions under the Superfund law or other laws or regulations regarding the remediation of waste. Except as noted below, the Companies do not believe this will have a material effect on results of operations, financial condition and/or cash flows.

In September 2011, the EPA issued a UAO to Virginia Power and 22 other parties, ordering specific remedial action of certain areas at the Ward Transformer Superfund site located in Raleigh, North Carolina. Virginia Power does not believe it is a liable party under CERCLA based on its alleged connection to the site. In November 2011, Virginia Power and a number of other parties notified the EPA that they are declining to undertake the work set forth in the UAO.

The EPA may seek to enforce a UAO in court pursuant to its enforcement authority under CERCLA, and may seek recovery of its costs in undertaking removal or remedial action. If the court determines that a respondent failed to comply with the UAO without sufficient cause, the EPA may also seek civil penalties of up to $37,500 per day for the violation and punitive damages of up to three times the costs incurred by the EPA as a result of the party's failure to comply with the UAO. Virginia Power is currently unable to make an estimate of the potential financial statement impacts related to the Ward Transformer matter.

Dominion has determined that it is associated with 17 former manufactured gas plant sites. Studies conducted by other utilities at their former manufactured gas plant sites have indicated that those sites contain coal tar and other potentially harmful materials. None of the 17 former sites with which Dominion is associated is under investigation by any state or federal environmental agency. At one of the former sites, Dominion is conducting a state-approved post closure groundwater monitoring program and an environmental land use restriction has been recorded. Another site has been accepted into a state-based voluntary remediation program and Dominion has not yet estimated the future remediation costs. Due to the uncertainty surrounding these sites, Dominion is unable to make an estimate of the potential financial statement impacts related to these sites.

Climate Change Legislation and Regulation

Massachusetts, Rhode Island and Connecticut, among other states, have joined RGGI, a multi-state effort to reduce CO₂ emissions in the Northeast implemented through state specific regulations. Under the initiative, aggregate CO₂ emissions from power plants in participating states are required to be stabilized at current levels from 2009 to 2015. Further reductions from current levels would be required to be phased in starting in 2016 such that by 2019 there would be a 10% reduction in participating state power plant CO₂ emissions. During 2012, RGGI will undergo a program review which could impact regulations and implementation of RGGI. The impact of this program review on Dominion's fossil fired generation operations in RGGI states is unknown at this time, and Dominion is currently unable to make an estimate of the potential financial statement impacts related to these matters.

Three of Dominion's facilities, Brayton Point, Salem Harbor and Manchester Street, are subject to RGGI. Beginning with calendar year 2009, RGGI requires that Dominion cover each ton of CO₂ direct stack emissions from these facilities with either an allowance or an offset. The allowances can be purchased through auction or through a secondary market. Dominion has periodically participated in RGGI allowance auctions to date and has procured allowances to meet its estimated compliance requirements under RGGI's current requirement for 2009 through 2014 and partially for 2015, therefore Dominion does not expect compliance with RGGI to have a material impact on its results of operations or financial condition. During June 2011, a lawsuit was filed in New York seeking to retroactively rescind RGGI participation by that state. A percentage of Dominion's RGGI allowances had been acquired from New York. The allocated value of these allowances totaled approximately $38 million, of which all have been expensed as consumed for RGGI Phase I compliance. In February 2012, Dominion surrendered these New York RGGI allowances for the RGGI Phase I compliance period and therefore does not expect any significant financial statement impacts from this lawsuit as it no longer holds allowances issued by the state of New York.

MF Global

Prior to October 31, 2011, certain of Dominion's subsidiaries executed certain commodity transactions on exchanges using MF Global, an FCM registered with the CFTC. In order to secure its potential exposure on these commodity transactions, Dominion posted certain required margin collateral with MF Global. The parent company of MF Global, MF Global Holdings Ltd., filed for bankruptcy relief under Chapter 11 of the U.S. Bankruptcy Code on October 31, 2011. On the same date, the U.S. District Court for the Southern District of New York appointed a trustee to oversee the liquidation of MF Global pursuant to the Securities Investor Protection Act.

In accordance with court-approved procedures, Dominion transferred to other FCMs all open positions executed using MF Global. The initial margin posted for these open positions at October 31, 2011 was approximately $73 million. Dominion has received approximately $8 million of this amount through the liquidation process to date.

At this time, the MF Global trustee is determining the final amounts that will be recoverable and ultimately distributed to MF Global's customers. As part of this process, the trustee has filed claims in the insolvency proceeding of MF Global affiliates in various foreign jurisdictions, including the United Kingdom, which claims are still pending. Due to the uncertainty surrounding the ultimate recovery on the claims filed by the MF Global trustee in the United Kingdom and elsewhere, the uncertain timing of such recovery, and the potential dilution of such recovered funds in the liquidation process, Dominion is unable to estimate the loss, if any, associated with its remaining margin claims or when it will receive any additional recoveries on such claims.

Nuclear Matters

In March 2011, a magnitude 9.0 earthquake and subsequent tsunami caused significant damage at the Fukushima Daiichi nuclear power station in northeast Japan. These events have resulted in significant nuclear safety reviews required by the NRC and industry groups such as INPO. Like other U.S. nuclear operators, Dominion has been gathering supporting data and participating in industry initiatives focused on the ability to respond to and mitigate the consequences of design-basis and beyond-design-basis events at its stations. 

In March 2012, the NRC issued orders and information requests requiring specific reviews and actions to all operating reactors, construction permit holders and combined license holders based on the lessons learned from the Fukushima Daiichi event. The orders applicable to Dominion require implementation of safety enhancements related to mitigation strategies to respond to extreme natural events resulting in the loss of power at plants, and enhancing spent fuel pool instrumentation. The orders require prompt implementation of the safety enhancements and completion of implementation within two refueling outages or by December 31, 2016, whichever comes first. Information requests issued by the NRC request each reactor to reevaluate the seismic and flooding hazards at their site using present-day methods and information, conduct walkdowns of their facilities to ensure protection against the hazards in their current design basis, and to reevaluate their emergency communications systems and staffing levels. These orders could require U.S. nuclear facilities, including those owned by Dominion and Virginia Power, to undertake plant modifications or perform additional analyses that may result in increased costs and capital requirements. Dominion and Virginia Power are evaluating the orders and information requests issued by the NRC and are currently unable to estimate the potential financial impacts related to these matters.

Guarantees

Dominion

At March 31, 2012, Dominion had issued $77 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of March 31, 2012, Dominion’s exposure under these guarantees was $45 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 its 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.

At March 31, 2012, Dominion had issued the following subsidiary guarantees:

	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	363	$	363
Commodity transactions(3)	3,360		273
Nuclear obligations(4)	231		62
Other(5)	481		44
Total	$	4,435	$	742

(1) Represents the estimated portion of the guarantee's stated limit that is utilized as of March 31, 2012 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, including subsidiaries of Virginia Power and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and 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 limits.

(4) 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.

(5) 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.

Surety Bonds and Letters of Credit

As of March 31, 2012, Dominion had purchased $155 million of surety bonds, including $62 million at Virginia Power, and authorized the issuance of standby letters of credit by financial institutions of $36 million, including $15 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.

Merchant Generation Operations

Dominion continually reviews its portfolio of assets to determine which assets fit strategically and support its objectives to improve return on invested capital and shareholder value. If Dominion identifies assets that do not support its objectives, it may consider such assets for divestiture. In connection with this effort, in the first quarter of 2011, Dominion decided to pursue the sale of Kewaunee. If these efforts are successful, Dominion may be required to present Kewaunee's assets and liabilities that are subject to sale as held for sale in its Consolidated Balance Sheet and Kewaunee's results of operations in discontinued operations in its Consolidated Statements of Income. Held for sale classification would require that amounts be recorded at the lower of book value or sale price less costs to sell and could result in the recording of an impairment charge. Any sale of Kewaunee would be subject to the approval of Dominion's Board of Directors, as well as applicable state and federal approvals.

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Investments

3 Months Ended

Mar. 31, 2012

Investments, Debt and Equity Securities [Abstract]

Investments

Investments

Dominion

Equity and Debt Securities

Rabbi Trust Securities

Marketable equity and debt securities and cash equivalents held in Dominion’s rabbi trusts and classified as trading totaled $95 million and $90 million at March 31, 2012 and December 31, 2011, respectively. Net unrealized gains on trading securities totaled $4 million and $3 million for the three months ended March 31, 2012 and 2011, respectively. Cost method investments held in Dominion’s rabbi trusts totaled $16 million and $17 million at March 31, 2012 and December 31, 2011, 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 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)
March 31, 2012
Marketable equity securities
U.S.:
Large Cap	$	1,178	$	724	$	—			$	1,902
Other	38		15		—				53
Marketable debt securities:
Corporate bonds	296		22		(1		)		317
U.S. Treasury securities and agency debentures	459		18		(1		)		476
State and municipal	267		21		—				288
Other	19		1		—				20
Cost method investments	117		—		—				117
Cash equivalents and other(2)	58		—		—				58
Total	$	2,432	$	801	$	(2	)	(3)	$	3,231
December 31, 2011
Marketable equity securities:
U.S.:
Large Cap	$	1,152	$	537	$	—			$	1,689
Other	36		10		—				46
Marketable debt securities:
Corporate bonds	314		19		(1		)		332
U.S. Treasury securities and agency debentures	437		20		(1		)		456
State and municipal	264		24		—				288
Other	23		1		—				24
Cost method investments	118		—		—				118
Cash equivalents and other(2)	46		—		—				46
Total	$	2,390	$	611	$	(2	)	(3)	$	2,999

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

(2) Includes pending purchases of securities of $20 million and $11 million at March 31, 2012 and December 31, 2011, respectively.

(3) The fair value of securities in an unrealized loss position was $192 million and $164 million at March 31, 2012 and December 31, 2011, respectively.

The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at March 31, 2012 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	62
Due after one year through five years	324
Due after five years through ten years	338
Due after ten years	377
Total	$	1,101

Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended March 31,
	2012		2011
(millions)
Proceeds from sales	$	415	$	502
Realized gains(1)	28		14
Realized losses(1)	4		8

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

Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds for Dominion were not material for the three months ended March 31, 2012 and 2011.

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 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)
March 31, 2012
Marketable equity securities:
U.S.:
Large Cap	$	469	$	294	$	—			$	763
Other	19		8		—				27
Marketable debt securities:
Corporate bonds	185		13		(1		)		197
U.S. Treasury securities and agency debentures	185		4		(1		)		188
State and municipal	121		8		—				129
Other	12		1		—				13
Cost method investments	117		—		—				117
Cash equivalents and other(2)	33		—		—				33
Total	$	1,141	$	328	$	(2	)	(3)	$	1,467
December 31, 2011
Marketable equity securities
U.S.:
Large Cap	$	460	$	218	$	—			$	678
Other	18		5		—				23
Marketable debt securities:
Corporate bonds	204		11		(1		)		214
U.S. Treasury securities and agency debentures	166		4		—				170
State and municipal	114		10		—				124
Other	16		1		(1		)		16
Cost method investments	118		—		—				118
Cash equivalents and other(2)	27		—		—				27
Total	$	1,123	$	249	$	(2	)	(3)	$	1,370

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

(2) Includes pending purchases of securities of $8 million and $13 million at March 31, 2012 and December 31, 2011, respectively.

(3) The fair value of securities in an unrealized loss position was $115 million and $99 million at March 31, 2012 and December 31, 2011, respectively.

The fair value of Virginia Power’s debt securities at March 31, 2012 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	2
Due after one year through five years	162
Due after five years through ten years	199
Due after ten years	164
Total	$	527

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

	Three Months Ended March 31,
	2012		2011
(millions)
Proceeds from sales	$	191	$	343
Realized gains(1)	11		5
Realized losses(1)	2		4

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

Other-than-temporary impairment losses on investments for Virginia Power were not material for the three months ended March 31, 2012 and 2011.

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Commitments and Contingencies (Narrative) (Details) (USD $)	3 Months Ended
	Mar. 31, 2012	Oct. 31, 2011
CAA authorized daily civil penalties for non compliance	$ 37,500
Estimated costs to install cooling towers	570,000,000
Amount of expenditures for cooling towers included in planned capital expenditures through 2012	65,000,000
Percent further emmision reduction goals in participating state power plant CO2 emissions	10.00%
Acquisition Cost Of Rggi Allowances	38,000,000
Exposure under guarantees	4,435,000,000
Purchased surety bonds	155,000,000
Authorized issuance of standby letters of credit	36,000,000
Third Party and Equity Method Investee
Issued guarantees	77,000,000
Exposure under guarantees	45,000,000
Minimum [Member]
CAA authorized daily civil penalties for non compliance	25,000
Maximum [Member]
CAA authorized daily civil penalties for non compliance	37,500
MF Global Bankruptcy
Initial margin posted		73,000,000
Margin received	$ 8,000,000

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Fair Value Measurements

3 Months Ended

Mar. 31, 2012

Fair Value Disclosures [Abstract]

Fair Value Measurements

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, 2011. See Note 7 in this report for further information about their derivatives and hedge accounting activities.

At March 31, 2012, Dominion's and Virginia Power's net balance of commodity derivatives categorized as Level 3 fair value measurements was a net liability of $61 million and $17 million, respectively.

Dominion's and Virginia Power's commodity derivative valuations are prepared by the ERM department. The ERM department reports directly to the Companies' CFO. The ERM department creates a daily computer-generated file containing mark-to-market valuations for the Companies' derivative transactions. Standard transactions are programmatically calculated using software. The inputs that go into the mark-to-market valuations are transactional information stored in the systems of record and market pricing information that resides in data warehouse databases. The majority of forward prices are automatically uploaded into the data warehouse databases from various third party sources. Inputs obtained from third party sources are evaluated for reliability considering the reputation, independence, market presence, and methodology used by the third party. If forward prices are not available from third party sources, then the ERM department models the forward prices based on other available market data. A team consisting of risk management and risk quantitative analysts meets each business day to assess the validity of market prices and mark-to-market valuations. During this meeting, the changes in mark-to-market valuations from period to period are examined and qualified against historical expectations. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

Dominion and Virginia Power use the discounted cash flow method to value Level 3 physical and financial forwards and futures and an option model to value Level 3 physical and financial options. The discounted cash flow model calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, price correlations, the original sales prices, and volumes. For Level 3 fair value measurements, the forward market prices, the implied price volatilities, and price correlations are considered unobservable. The unobservable inputs are developed and substantiated using historical information, available market data, third party data, and statistical analysis. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources.

The following table presents Dominion's quantitative information about Level 3 fair value measurements. Included are descriptions of the valuation techniques, the significant unobservable inputs, and the range of market price, price correlation and price volatility inputs used in the fair value measurements at March 31, 2012 for each category of transaction and commodity type. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility and correlations.

	Fair Value (millions)		Valuation Technique(s)	Unobservable Input		Range	Weighted Average(1)
At March 31, 2012
Assets:
Physical and Financial Forwards and Futures:
Natural Gas(2)	$	31	Discounted Cash Flow	Market Price (per Dth)	(3)	(1) - 6	3
Electricity	69		Discounted Cash Flow	Market Price (per MWh)	(3)	21 - 61	43
FTRs	1		Discounted Cash Flow	Market Price (per MWh)	(3)	(3) - 3	—
Capacity	9		Discounted Cash Flow	Market Price (per MW)	(3)	95-120	101
Liquids	1		Discounted Cash Flow	Market Price (per Gal)	(3)	1 - 2	1
Physical and Financial Options:
Natural Gas	6		Option Model	Market Price (per Dth)	(3)	2 - 5	4
				Price Volatility	(4)	23% - 60%	30	%
				Price Correlation	(5)	100% - 100%	100	%
Total assets	$	117
Liabilities:
Physical and Financial Forwards and Futures:
Natural Gas(2)	$	21	Discounted Cash Flow	Market Price (per Dth)	(3)	(1) - 6	3
Electricity	17		Discounted Cash Flow	Market Price (per MWh)	(3)	12 - 61	41
FTRs	18		Discounted Cash Flow	Market Price (per MWh)	(3)	(6) - 5	—
Liquids	108		Discounted Cash Flow	Market Price (per Gal)	(3)	1 - 3	2
Physical and Financial Options:
Natural Gas(2)	14		Option Model	Market Price (per Dth)	(3)	(1) - 5	2
				Price Volatility	(4)	23% - 59%	36	%
				Price Correlation	(5)	70% - 100%	90	%
Total liabilities	$	178

(1) Averages weighted by volume.

(2) Includes basis.

(3) Represents market prices beyond defined terms for Levels 1 & 2.

(4) Represents volatilities unrepresented in published markets.

(5) Represents intra-price correlations for which markets do not exist.

The following table presents Virginia Power's quantitative information about Level 3 fair value measurements. Included are descriptions of the valuation techniques, the significant unobservable inputs, and the range of market price inputs used in the fair value measurements at March 31, 2012 for each category of transaction and commodity type. The range and weighted average are presented in dollars for market price inputs.

	Fair Value (millions)		Valuation Technique(s)	Unobservable Input		Range	Weighted Average(1)
At March 31, 2012
Assets:
Physical and Financial Forwards and Futures:
FTRs	$	1	Discounted Cash Flow	Market Price (per MWh)	(2)	(3) - 3	0
Total assets	$	1
Liabilities:
Physical and Financial Forwards and Futures:
FTRs	$	18	Discounted Cash Flow	Market Price (per MWh)	(2)	(6) - 3	0
Total liabilities	$	18

(1) Averages weighted by volume.

(2) Represents market prices beyond defined terms for Levels 1 & 2.

Sensitivity of the fair value measurements to changes in the significant unobservable inputs is as follows:

Significant Unobservable Inputs	Position	Change to Input	Impact on Fair Value Measurement
Market Price	Buy	Increase (decrease)	Gain (loss)
Market Price	Sell	Increase (decrease)	Loss (gain)
Price Volatility	Buy	Increase (decrease)	Gain (loss)
Price Volatility	Sell	Increase (decrease)	Loss (gain)
Price Correlation	Buy	Increase (decrease)	Loss (gain)
Price Correlation	Sell	Increase (decrease)	Gain (loss)

Non-recurring Fair Value Measurements

During March 2011, Dominion determined that it was unlikely that State Line would participate in the May 2011 PJM capacity base residual auction that would commit State Line's capacity from June 2014 through May 2015.  This determination reflected an expectation that margins for coal-fired generation will remain compressed in the 2014 and 2015 period in combination with the expectation that State Line may be impacted during the same time period by environmental regulations that would likely require significant capital expenditures. As a result, Dominion evaluated State Line for impairment since it was more likely than not that State Line would be retired before the end of its previously estimated useful life. As a result of this evaluation, Dominion recorded an impairment charge of $55 million ($39 million after-tax) reflected 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 less than $1 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 used the income approach (discounted cash flows) to estimate the fair value of State Line's long-lived assets in the impairment test. 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. State Line was retired in March 2012.

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)
At March 31, 2012
Assets:
Derivatives:
Commodity	$	54	$	1,007	$	117	$	1,178
Interest rate	—		94		—		94
Investments(1):
Equity securities:
U.S.:
Large cap	1,933		—		—		1,933
Other	59		—		—		59
Non-U.S.:
Large cap	11		—		—		11
Fixed income:
Corporate debt instruments	—		317		—		317
U.S. Treasury securities and agency debentures	308		170		—		478
State and municipal	—		328		—		328
Other	—		20		—		20
Cash equivalents and other	—		82		—		82
Restricted cash equivalents	—		104		—		104
Total assets	$	2,365	$	2,122	$	117	$	4,604
Liabilities:
Derivatives:
Commodity	$	19	$	737	$	178	$	934
Interest rate	—		176		—		176
Total liabilities	$	19	$	913	$	178	$	1,110
At December 31, 2011
Assets:
Derivatives:
Commodity	$	44	$	828	$	93	$	965
Interest rate	—		105		—		105
Investments(1):
Equity securities:
U.S.:
Large cap	1,718		—		—		1,718
Other	51		—		—		51
Non-U.S.:
Large cap	10		—		—		10
Fixed income:
Corporate debt instruments	—		332		—		332
U.S. Treasury securities and agency debentures	277		181		—		458
State and municipal	—		329		—		329
Other	—		23		—		23
Cash equivalents and other	—		60		—		60
Restricted cash equivalents	—		141		—		141
Total assets	$	2,100	$	1,999	$	93	$	4,192
Liabilities:
Derivatives:
Commodity	$	10	$	714	$	164	$	888
Interest rate	—		269		—		269
Total liabilities	$	10	$	983	$	164	$	1,157

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

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 March 31,
	2012			2011
(millions)
Beginning balance	$	(71	)	$	(50	)
Total realized and unrealized gains (losses):
Included in earnings	(35		)	14
Included in other comprehensive income (loss)	5			(94		)
Included in regulatory assets/liabilities	11			(21		)
Settlements	30			(16		)
Transfers out of Level 3	(1		)	4
Ending balance	$	(61	)	$	(163	)
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	$	1		$	4

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			Total
(millions)
Three Months Ended March 31, 2012
Total gains (losses) included in earnings	$	(9	)	$	(26	)	$	(35	)
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	1			—			1
Three Months Ended March 31, 2011
Total gains (losses) included in earnings	$	(2	)	$	16		$	14
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

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)
At March 31, 2012
Assets:
Derivatives:
Commodity	$	—	$	—	$	1	$	1
Investments(1):
Equity securities:
U.S.:
Large cap	764		—		—		764
Other	27		—		—		27
Fixed income:
Corporate debt instruments	—		197		—		197
U.S. Treasury securities and agency debentures	123		65		—		188
State and municipal	—		129		—		129
Other	—		13		—		13
Cash equivalents and other	—		41		—		41
Restricted cash equivalents	—		29		—		29
Total assets	$	914	$	474	$	1	$	1,389
Liabilities:
Derivatives:
Commodity	$	—	$	21	$	18	$	39
Interest rate	—		38		—		38
Total liabilities	$	—	$	59	$	18	$	77
At December 31, 2011
Assets:
Derivatives:
Commodity	$	—	$	—	$	2	$	2
Investments(1):
Equity securities:
U.S.:
Large cap	679		—		—		679
Other	23		—		—		23
Fixed income:
Corporate debt instruments	—		214		—		214
U.S. Treasury securities and agency debentures	107		63		—		170
State and municipal	—		125		—		125
Other	—		16		—		16
Cash equivalents and other	—		40		—		40
Restricted cash equivalents	—		32		—		32
Total assets	$	809	$	490	$	2	$	1,301
Liabilities:
Derivatives:
Commodity	$	—	$	17	$	30	$	47
Interest rate	—		100		—		100
Total liabilities	$	—	$	117	$	30	$	147

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

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 March 31,
	2012			2011
(millions)
Beginning balance	$	(28	)	$	14
Total realized and unrealized gains (losses):
Included in earnings	(27		)	16
Included in regulatory assets/liabilities	11			(21		)
Settlements	27			(16		)
Ending balance	$	(17	)	$	(7	)

The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases in Virginia Power's Consolidated Statements of Income for the three months ended March 31, 2012 and 2011. 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 months ended March 31, 2012 and 2011.

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:

	March 31, 2012				December 31, 2011
	Carrying Amount		Estimated Fair Value(1)		Carrying Amount			Estimated Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	16,695	$	19,256	$	16,264	18,936	$	18,936
Long-term debt, VIE(3)	882		889		890		892	892
Junior subordinated notes payable to affiliates	268		272		268		268	268
Enhanced junior subordinated notes	1,365		1,437		1,451		1,518	1,518
Subsidiary preferred stock(4)	257		259		257		256	256
Virginia Power
Long-term debt, including securities due within one year(2)	$	7,308	$	8,628	$	6,862		$	8,281
Preferred stock(4)	257		259		257			256

(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. All fair value measurements are classified as Level 2. 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 March 31, 2012 and December 31, 2011, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $93 million and $105 million, respectively.

(3) Includes amounts which represent the unamortized premium.

(4) Includes deferred issuance expenses of $2 million at March 31, 2012 and December 31, 2011.

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Derivatives and Hedge Accounting Activities

3 Months Ended

Mar. 31, 2012

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives and Hedge Accounting Activities

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, 2011. See Note 6 in this report for further information about fair value measurements and associated valuation methods for derivatives.

Dominion

The following table presents the volume of Dominion’s derivative activity as of March 31, 2012. 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 transactions, 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)	315		74
Basis(1)	861		484
Electricity (MWh):
Fixed price(1)	21,953,642		21,718,420
FTRs	21,805,241		810,816
Capacity (MW)	63,825		272,968
Liquids (gallons)(2)	137,508,000		221,214,000
Interest rate	$	2,000,000,000	$	1,940,000,000

(1) Includes options.

(2) Includes NGLs and oil.

For the three months ended March 31, 2012, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness 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.

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion’s Consolidated Balance Sheet at March 31, 2012:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	(30	)	$	(16	)	33 months
Electricity	243			102			45 months
NGLs	(64		)	(27		)	33 months
Other	6			2			38 months
Interest rate	(97		)	(12		)	369 months
Total	$	58		$	49

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 and interest rates.

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)
March 31, 2012
ASSETS
Current Assets
Commodity	$	312	$	472	$	784
Interest rate	38		—		38
Total current derivative assets	350		472		822
Noncurrent Assets
Commodity	295		99		394
Interest rate	56		—		56
Total noncurrent derivative assets(1)	351		99		450
Total derivative assets	$	701	$	571	$	1,272
LIABILITIES
Current Liabilities
Commodity	$	206	$	492	$	698
Interest rate	158		15		173
Total current derivative liabilities	364		507		871
Noncurrent Liabilities
Commodity	151		85		236
Interest rate	—		3		3
Total noncurrent derivative liabilities(2)	151		88		239
Total derivative liabilities	$	515	$	595	$	1,110
December 31, 2011
ASSETS
Current Assets
Commodity	$	176	$	495	$	671
Interest rate	34		—		34
Total current derivative assets	210		495		705
Noncurrent Assets
Commodity	198		96		294
Interest rate	71		—		71
Total noncurrent derivative assets(1)	269		96		365
Total derivative assets	$	479	$	591	$	1,070
LIABILITIES
Current Liabilities
Commodity	$	162	$	530	$	692
Interest rate	222		37		259
Total current derivative liabilities	384		567		951
Noncurrent Liabilities
Commodity	118		78		196
Interest rate	—		10		10
Total noncurrent derivative liabilities(2)	118		88		206
Total derivative liabilities	$	502	$	655	$	1,157

(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.

The following tables present the gains and losses on Dominion's derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:

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 March 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	64
Purchased gas				(30		)
Electric fuel and other energy-related purchases				(7		)
Total commodity	$	176		27			$	(1	)
Interest rate(3)	32			1			27
Total	$	208		$	28		$	26
Three Months Ended March 31, 2011
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	28
Purchased gas				(48		)
Electric fuel and other energy-related purchases				1
Purchased electric capacity				1
Total commodity	$	(142	)	(18		)	$	(5	)
Interest rate(3)	(1		)	—			(1		)
Total	$	(143	)	$	(18	)	$	(6	)

(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.

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended March 31,
Derivatives not designated as hedging instruments	2012			2011
(millions)
Derivative Type and Location of Gains (Losses)
Commodity
Operating revenue	$	69		$	19
Purchased gas	(10		)	(11		)
Electric fuel and other energy-related purchases	(27		)	16
Interest rate(2)	(2		)	—
Total	$	30		$	24

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

Virginia Power

The following table presents the volume of Virginia Power’s derivative activity as of March 31, 2012. 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 transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price	21		—
Basis	10		—
Electricity (MWh):
Fixed price	664,000		—
FTRs	20,365,031		195,840
Capacity (MW)	30,500		182,500
Interest rate	$	750,000,000	$	90,000,000

For the three months ended March 31, 2012 and 2011, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness 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.

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)
March 31, 2012
ASSETS
Current Assets
Commodity	$	—	$	1	$	1
Total current derivative assets(1)	—		1		1
Total derivative assets	$	—	$	1	$	1
LIABILITIES
Current Liabilities
Commodity	$	17	$	20	$	37
Interest rate	20		15		35
Total current derivative liabilities(2)	37		35		72
Noncurrent Liabilities
Commodity	2		—		2
Interest rate	—		3		3
Total noncurrent derivative liabilities(3)	2		3		5
Total derivative liabilities	$	39	$	38	$	77
December 31, 2011
ASSETS
Current Assets
Commodity	$	—	$	2	$	2
Total current derivative assets(1)	—		2		2
Total derivative assets	$	—	$	2	$	2
LIABILITIES
Current Liabilities
Commodity	$	14	$	31	$	45
Interest rate	53		37		90
Total current derivative liabilities(2)	67		68		135
Noncurrent Liabilities
Commodity	2		—		2
Interest rate	—		10		10
Total noncurrent derivative liabilities(3)	2		10		12
Total derivative liabilities	$	69	$	78	$	147

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

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

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

The following tables present the gains and losses on Virginia Power's derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:

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 March 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(2	)
Total commodity	$	(2	)	(2		)	$	(1	)
Interest rate(3)	1			—			27
Total	$	(1	)	$	(2	)	$	26
Three Months Ended March 31, 2011
Derivative Type and Location of Gains (Losses)
Commodity:
Purchased electric capacity				$	1
Total commodity	$	—		1			$	(5	)
Interest rate(3)	—			—			(1		)
Total	$	—		$	1		$	(6	)

(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.

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months  Ended March 31,
Derivatives not designated as hedging instruments	2012			2011
(millions)
Derivative Type and Location of Gains (Losses)
Commodity(2)	$	(27	)	$	16
Interest rate(3)	(2		)	—
Total	$	(29	)	$	16

(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.

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Regulatory Matters

3 Months Ended

Mar. 31, 2012

Regulatory Matters [Abstract]

Regulatory Matters

Regulatory Matters

Regulatory Matters Involving Potential Loss Contingencies

As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. This estimated range is based on currently available information and involves elements of judgment and significant uncertainties. This estimated range of possible loss does not represent the Companies' maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on Dominion's or Virginia Power's financial position, liquidity or results of operations.

FERC - Electric

Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public utilities. Virginia Power purchases and sells electricity in the PJM wholesale market and Dominion's merchant generators sell electricity in the PJM, MISO and ISO-NE wholesale markets under Dominion's market-based sales tariffs authorized by FERC. In addition, Virginia Power has FERC approval of a tariff to sell wholesale power at capped rates based on its embedded cost of generation. This cost-based sales tariff could be used to sell to loads within or outside Virginia Power's service territory. Any such sales would be voluntary.

Rates

In April 2008, FERC granted an application for Virginia Power's electric transmission operations to establish a forward-looking formula rate mechanism that updates transmission rates on an annual basis and approved an ROE of 11.4%, effective as of January 1, 2008. The formula rate is designed to recover the expected revenue requirement for each calendar year and is updated based on actual costs. The FERC-approved formula method, which is based on projected costs, allows Virginia Power to earn a current return on its growing investment in electric transmission infrastructure.

In July 2008, Virginia Power filed an application with FERC requesting a revision to its revenue requirement to reflect an additional ROE incentive adder for eleven electric transmission enhancement projects. Under the proposal, the cost of transmission service would increase to include an ROE incentive adder for each of the eleven projects, beginning the date each project enters commercial operation (but not before January 1, 2009). Virginia Power proposed an incentive of 1.5% for four of the projects and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008. All eleven projects are currently expected to be completed by the end of 2012. Numerous parties sought rehearing of the FERC order in August 2008, and rehearing is pending. Although Virginia Power cannot predict the outcome of the rehearing, it is not expected to have a material effect on results of operations.

In March 2010, ODEC and NCEMC filed a complaint with FERC against Virginia Power 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.  In February 2012, Virginia Power submitted to FERC a settlement agreement to resolve all issues set for hearing.  All transmission customer parties to the proceeding joined the settlement. The Virginia Commission, North Carolina Commission and Public Staff of the North Carolina Commission, while not parties to the settlement, have agreed to not oppose the settlement.  If accepted by FERC, the settlement provides for payment by Virginia Power to the transmission customer parties collectively of $250,000 per year for ten years and resolves all matters other than the incremental cost of certain underground transmission facilities, which will be set for briefing.  While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations.

PJM

In November 2011, PJM issued a formal notification that it would recalculate certain ancillary service revenues that had previously been paid during 2009, 2010 and 2011. Also in November 2011, PJM requested FERC permission to suspend its rebilling and repayment obligations associated with the recalculation of such revenues and petitioned FERC to establish a proceeding to determine the appropriate recalculations for the revenues during this period.  In December 2011, FERC permitted the suspension of rebilling and repayment by PJM, subject to the outcome of FERC's proceedings to determine the appropriate revenue recalculation. In April 2012, FERC issued an Order Establishing Hearing and Settlement Judge Procedures to address the appropriate recalculation of the ancillary service credits PJM will be required to collect from Virginia Power. Virginia Power has accrued a liability of $36 million as of March 31, 2012 for estimated future billing adjustments from PJM related to the ancillary service revenues.  

Other 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, 2011.

Virginia Regulation

Biennial Review

In November 2011, the Virginia Commission issued the Biennial Review Order, which included a determination that Virginia Power's new authorized ROE is 10.9%, inclusive of a performance incentive of 50 basis points for meeting certain RPS targets. In December 2011, Virginia Power filed a petition with the Virginia Commission seeking rehearing or reconsideration of the Biennial Review Order, to confirm the effective date of the newly authorized 10.9% base ROE. Virginia Power's petition requested the Virginia Commission to confirm that the 10.9% ROE authorized in the Biennial Review Order would apply prospectively, effective following the date of the Biennial Review Order on November 30, 2011, and that Virginia Power's previously-approved 11.9% base ROE authorized in the Virginia Settlement Approval Order would be used to measure base rate earnings for the period January 1, 2011 through November 30, 2011. In March 2012, the Virginia Commission issued an order denying Virginia Power's petition seeking rehearing or reconsideration. Contrary to Virginia Power's position, the Virginia Commission ruled that the new 10.9% ROE will be used to measure earnings for the entire 2011-2012 test period in the next biennial review in 2013. Also in March 2012, Virginia Power filed Petitions for Appeal with the Supreme Court of Virginia regarding the Biennial Review Order and the March 2012 order.

In the Biennial Review Order, the Virginia Commission declined to award a performance incentive for generating plant performance, customer service or operating efficiency in connection with the 2009-2010 biennial review. Instead, in March 2012, the Virginia Commission issued an order initiating a rulemaking proceeding to develop specific performance metrics and nationally recognized standards for determining positive or negative performance incentives for electric utilities. Such incentive criteria would be applied in future biennial review proceedings. Virginia Power expects the Staff of the Virginia Commission to file proposed rules and regulations for performance incentives in September 2012.

Generation Riders R and S

In March 2012, the Virginia Commission approved annual updates for Riders R and S for the April 1, 2012 to March 31, 2013 rate year, utilizing an 11.4% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The Virginia Commission's approvals authorized an approximately $74 million revenue requirement for Rider R, and an approximately $226 million revenue requirement for Rider S, comprised of approximately $52 million for the pre-commercial operation period and approximately $174 million for the commercial operation period.

Generation Rider B

In March 2012, the Virginia Commission approved the conversion of the Altavista, Hopewell, and Southampton power stations to biomass. The conversions will increase Dominion's renewable generation by more than 150 MW. The conversions are expected to be completed by the end of 2013.

As part of its approval, the Virginia Commission also approved Rider B. The approved revenue requirement for Rider B is approximately $6 million for the April 1, 2012 to March 31, 2013 rate year, utilizing a 12.4% ROE (inclusive of a 200 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The renewable generating unit statutory enhancement of 200 basis points will apply during construction and the first five years of the service lives of the converted facilities.

North Carolina Regulation

In March 2012, Virginia Power filed an application with the North Carolina Commission to increase base non-fuel revenues by approximately $64 million, with January 1, 2013 as the proposed effective date for the permanent rate revision. Virginia Power plans to file an application in August 2012 to decrease its fuel rates. The net effect of the proposed change in base rates and current estimate of fuel charges would be a net revenue increase of approximately $37 million. Virginia Power intends to implement rates on a temporary basis, subject to refund, on November 1, 2012, as permitted by North Carolina law. Virginia Power expects to receive an order from the North Carolina Commission in December 2012.

Ohio Regulation

In February 2012, East Ohio submitted an application with the Ohio Commission to adjust the cost recovery charge for costs associated with PIR investments for the six months ended December 31, 2011. The filing was made in accordance with changes to the PIR program approved by the Ohio Commission in August 2011 and effects a transition from a fiscal year ending June 30 to a calendar year for annual filings thereafter. The application includes total gross plant investment for the six-month July 1-December 31, 2011 transition period of $73 million, cumulative gross plant investment of $362 million, and a revenue requirement of $47 million. A stipulation was submitted by East Ohio, the Staff of the Ohio Commission and the Ohio Consumers' Counsel that supports the rates filed by East Ohio. The Ohio Commission issued an order approving the stipulation in April 2012.

FERC Gas - Cove Point Rate Case

In May 2011, Cove Point filed a general rate case for its FERC-jurisdictional services, with proposed rates to be effective July 1, 2011. In June 2011, FERC accepted a July 1, 2011 effective date for all proposed rates but two, for which the effective date was suspended from July 1 to December 1, 2011. In December 2011, Cove Point, FERC trial staff and the other active parties in the rate case reached a settlement in principle on all issues set for hearing by FERC, as well as on all outstanding proposed tariff changes filed in May 2011. In April 2012, Cove Point filed a stipulation and agreement resolving all outstanding issues in the rate case and establishing the mechanism for operational purchases of LNG. The settlement is subject to FERC approval. Settlement rates and tariff changes will be effective retroactive to April 1, 2012, once the FERC order approving the settlement is no longer subject to rehearing or appeal. Cove Point and settling customers will be subject to a rate moratorium through December 31, 2016. Cove Point is required to file its next rate case with rates to be effective January 1, 2017.

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Employee Benefit Plans (Narrative) (Details) (USD $)	3 Months Ended
	Mar. 31, 2012
Compensation and Retirement Disclosure [Abstract]
Dominion contribution	$ 0
Expected contribution to voluntary employees' beneficiary association	$ 16,000,000

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Operating Segments (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Costs and Expenses	$ 2,577	$ 3,094
After Tax Net Benefits Expenses Attributable To Operating Segments	0
Operating Loss	(915)	(963)
Corporate and Other
Costs and Expenses	7	62
After Tax Net Benefits Expenses Attributable To Operating Segments		54
Dominion Generation
Impairment charges		55
Impairment charges, after-tax		39
Operating Loss		32
Operating Loss After Tax		$ 19

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Related Party Transactions (Details) (Virginia Electric and Power Company [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011
Virginia Electric and Power Company [Member]
Related Party Transaction [Line Items]
Commodity purchases from affiliates	$ 78	$ 62
Services provided by affiliates	96	93
Related Party Outstanding Borrowing For Non Regulated Subsidiaries	$ 187		$ 187

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Employee Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2012

Compensation and Retirement Disclosure [Abstract]

Net Periodic Benefit Cost

The components of Dominion's provision for net periodic benefit cost were as follows:

	Pension Benefits						Other Postretirement Benefits
	2012			2011			2012			2011
(millions)
Three Months Ended March 31,
Service cost	$	29		$	27		$	11		$	12
Interest cost	67			64			20			23
Expected return on plan assets	(108		)	(110		)	(21		)	(20		)
Amortization of prior service cost (credit)	1			1			(3		)	(3		)
Amortization of net loss	33			24			2			3
Net periodic benefit cost	$	22		$	6		$	9		$	15

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Derivatives and Hedge Accounting Activities (Schedule of Derivatives not Designated as Hedging Instruments) (Details) (Fair Value - Derivatives not under Hedge Accounting [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 30	[1]	$ 24	[1]
Interest Rate Contract [Member]
Amount of Gain (Loss) Recognized in Income on Derivatives	(2)	[1],[2]	0	[1],[2]
Commodity Contract [Member] | Operating revenue [Member]
Amount of Gain (Loss) Recognized in Income on Derivatives	69	[1]	19	[1]
Commodity Contract [Member] | Purchased Gas [Member]
Amount of Gain (Loss) Recognized in Income on Derivatives	(10)	[1]	(11)	[1]
Commodity Contract [Member] | Electric Fuel and Other Energy Related Purchases [Member]
Amount of Gain (Loss) Recognized in Income on Derivatives	$ (27)	[1]	$ 16	[1]

[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 recorded in Dominion’s Consolidated Statements of Income are classified in interest and related charges.

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Related Party Transactions

3 Months Ended

Mar. 31, 2012

Related Party Transactions [Abstract]

Related Party Transactions

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 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 risk associated with purchases of natural gas.

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

Presented below are significant transactions with DRS and other affiliates:

	Three Months Ended March 31,
	2012		2011
(millions)
Commodity purchases from affiliates	$	78	$	62
Services provided by affiliates	96		93

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 $187 million as of both March 31, 2012 and December 31, 2011. There were no short-term demand note borrowings from Dominion as of March 31, 2012 and December 31, 2011. Interest charges related to Virginia Power's borrowings from Dominion were immaterial for the three months ended March 31, 2012 and 2011, respectively.

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2012

Income Tax Disclosure [Abstract]

Effective Income Tax

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
Three Months Ended March 31,	2012		2011		2012		2011
U.S. statutory rate	35.0	%	35.0	%	35.0	%	35.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.8		3.7		3.9		3.9
Valuation allowances	(2.7	)	0.8		—		—
AFUDC - equity	(0.7	)	(0.7	)	(0.9	)	(1.1	)
Other, net	(1.3	)	0.3		(0.2	)	0.2
Effective tax rate	34.1	%	39.1	%	37.8	%	38.0	%

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Derivatives and Hedge Accounting Activities (Fair Value of Derivatives) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012		Dec. 31, 2011
Total Fair Value, Assets	$ 1,272		$ 1,070
Total Fair Value, Liabilities	1,110		1,157
Current Assets
Total Fair Value, Assets	822		705
Current Assets | Commodity Contract [Member]
Total Fair Value, Assets	784		671
Current Assets | Interest Rate Contract [Member]
Total Fair Value, Assets	38		34
Noncurrent Assets
Total Fair Value, Assets	450	[1]	365	[1]
Noncurrent Assets | Commodity Contract [Member]
Total Fair Value, Assets	394		294
Noncurrent Assets | Interest Rate Contract [Member]
Total Fair Value, Assets	56		71
Current Liabilities
Total Fair Value, Liabilities	871		951
Current Liabilities | Commodity Contract [Member]
Total Fair Value, Liabilities	698		692
Current Liabilities | Interest Rate Contract [Member]
Total Fair Value, Liabilities	173		259
Noncurrent Liabilities
Total Fair Value, Liabilities	239	[2]	206	[2]
Noncurrent Liabilities | Commodity Contract [Member]
Total Fair Value, Liabilities	236		196
Noncurrent Liabilities | Interest Rate Contract [Member]
Total Fair Value, Liabilities	3		10
Fair Value - Derivatives under Hedge Accounting
Total Fair Value, Assets	701		479
Total Fair Value, Liabilities	515		502
Fair Value - Derivatives under Hedge Accounting | Current Assets
Total Fair Value, Assets	350		210
Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity Contract [Member]
Total Fair Value, Assets	312		176
Fair Value - Derivatives under Hedge Accounting | Current Assets | Interest Rate Contract [Member]
Total Fair Value, Assets	38		34
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets
Total Fair Value, Assets	351	[1]	269	[1]
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Commodity Contract [Member]
Total Fair Value, Assets	295		198
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Interest Rate Contract [Member]
Total Fair Value, Assets	56		71
Fair Value - Derivatives under Hedge Accounting | Current Liabilities
Total Fair Value, Liabilities	364		384
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Commodity Contract [Member]
Total Fair Value, Liabilities	206		162
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Interest Rate Contract [Member]
Total Fair Value, Liabilities	158		222
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities
Total Fair Value, Liabilities	151	[2]	118	[2]
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity Contract [Member]
Total Fair Value, Liabilities	151		118
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest Rate Contract [Member]
Total Fair Value, Liabilities	0		0
Fair Value - Derivatives not under Hedge Accounting
Total Fair Value, Assets	571		591
Total Fair Value, Liabilities	595		655
Fair Value - Derivatives not under Hedge Accounting | Current Assets
Total Fair Value, Assets	472		495
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity Contract [Member]
Total Fair Value, Assets	472		495
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Interest Rate Contract [Member]
Total Fair Value, Assets	0		0
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets
Total Fair Value, Assets	99	[1]	96	[1]
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity Contract [Member]
Total Fair Value, Assets	99		96
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Interest Rate Contract [Member]
Total Fair Value, Assets	0		0
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities
Total Fair Value, Liabilities	507		567
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity Contract [Member]
Total Fair Value, Liabilities	492		530
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Interest Rate Contract [Member]
Total Fair Value, Liabilities	15		37
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities
Total Fair Value, Liabilities	88	[2]	88	[2]
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity Contract [Member]
Total Fair Value, Liabilities	85		78
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest Rate Contract [Member]
Total Fair Value, Liabilities	$ 3		$ 10

[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.

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Fair Value Measurements (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
Fair Value, Measurements, Nonrecurring | Other Operating Expense
State line evaluation, impairment charge	$ 55
State line evaluation, impairment charge after tax	39
Fair Value, Measurements, Nonrecurring | Other Operating Expense | State Line
State line evaluation, impairment charge	1
Level 3 | Commodity Transactions
Commodity derivatives categorized as Level 3 fair value measurements, net asset	$ 61

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Consolidated Balance Sheets (USD $) In Millions, unless otherwise specified	Mar. 31, 2012		Dec. 31, 2011
Current Assets
Cash and cash equivalents	$ 133		$ 102	[1]
Customer receivables (less allowance for doubtful accounts)	1,539		1,780	[1]
Other receivables (less allowance for doubtful accounts)	173		255	[1]
Inventories	1,249		1,348	[1]
Derivative assets	822		705	[1]
Other	1,103		1,240	[1]
Total current assets	5,019		5,430	[1]
Investments
Nuclear decommissioning trust funds	3,231		2,999	[1]
Investment in equity method affiliates	552		553	[1]
Restricted cash equivalents	104		141	[1]
Other	296		292	[1]
Total investments	4,183		3,985	[1]
Property, Plant and Equipment
Property, plant and equipment	42,895		42,033	[1]
Property, plant and equipment, VIE	957		957	[1]
Accumulated depreciation, depletion and amortization	(13,564)		(13,320)	[1]
Total property, plant and equipment, net	30,288		29,670	[1]
Deferred Charges and Other Assets
Goodwill	3,141		3,141	[1]
Regulatory assets	1,319		1,382	[1]
Other	2,143		2,006	[1]
Total deferred charges and other assets	6,603		6,529	[1]
Total assets	46,093		45,614	[1]
Current Liabilities
Securities due within one year	2,131		1,479	[1]
Short-term debt	1,057		1,814	[1]
Accounts payable	935		1,250	[1]
Derivative liabilities	871		951	[1]
Other	1,660		1,468	[1]
Total current liabilities	6,654		6,962	[1]
Long-Term Debt
Long-term debt	14,564		14,785	[1]
Long-term debt, VIE	882		890	[1]
Junior subordinated notes payable to affiliates	268		268	[1]
Enhanced junior subordinated notes	1,365		1,451	[1]
Total long-term debt	17,079		17,394	[1]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits	5,719		5,216	[1]
Asset retirement obligations	1,396		1,383	[1]
Regulatory liabilities	1,423		1,324	[1]
Other	1,596		1,575	[1]
Total deferred credits and other liabilities	10,134		9,498	[1]
Total liabilities	33,867		33,854	[1]
Commitments and Contingencies (see Note 12)				[1]
Subsidiary Preferred Stock Not Subject to Mandatory Redemption	257		257	[1]
Equity
Common stock - no par	5,256	[2]	5,180	[1],[2]
Other paid-in capital	173		179	[1]
Retained earnings	6,891		6,697	[1]
Accumulated other comprehensive income (loss)	(411)		(610)	[1]
Total common shareholders' equity	11,909		11,446	[1]
Noncontrolling interest	60		57	[1]
Total equity	11,969		11,503	[1]
Total liabilities and equity	46,093		45,614	[1]
Virginia Electric and Power Company [Member]
Current Assets
Cash and cash equivalents	28		29	[3]
Customer receivables (less allowance for doubtful accounts)	789		892	[3]
Other receivables (less allowance for doubtful accounts)	127		145	[3]
Inventories	777		797	[3]
Prepayments	29		41	[3]
Other	373		532	[3]
Total current assets	2,123		2,436	[3]
Investments
Nuclear decommissioning trust funds	1,467		1,370	[3]
Other	32		36	[3]
Total investments	1,499		1,406	[3]
Property, Plant and Equipment
Property, plant and equipment	29,136		28,626	[3]
Accumulated depreciation, depletion and amortization	(9,758)		(9,615)	[3]
Total property, plant and equipment, net	19,378		19,011	[3]
Deferred Charges and Other Assets
Intangible assets	185		183	[3]
Regulatory assets	345		399	[3]
Other	86		109	[3]
Total deferred charges and other assets	616		691	[3]
Total assets	23,616		23,544	[3]
Current Liabilities
Securities due within one year	1,016		616	[3]
Short-term debt	255		894	[3]
Accounts payable	395		405	[3]
Payables to affiliates	54		108	[3]
Affiliated current borrowings	187		187	[3]
Accrued interest, payroll and taxes	363		226	[3]
Other	520		685	[3]
Total current liabilities	2,790		3,121	[3]
Long-Term Debt
Total long-term debt	6,292		6,246	[3]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits	3,339		3,180	[3]
Asset retirement obligations	628		624	[3]
Regulatory liabilities	1,191		1,095	[3]
Other	270		271	[3]
Total deferred credits and other liabilities	5,428		5,170	[3]
Total liabilities	14,510		14,537	[3]
Commitments and Contingencies (see Note 12)				[3]
Subsidiary Preferred Stock Not Subject to Mandatory Redemption	257		257	[3]
Equity
Common stock - no par	5,738	[4]	5,738	[3],[4]
Other paid-in capital	1,111		1,111	[3]
Retained earnings	1,973		1,882	[3]
Accumulated other comprehensive income (loss)	27		19	[3]
Total common shareholders' equity	8,849		8,750	[3]
Total liabilities and equity	$ 23,616		$ 23,544	[3]

[1] Dominion’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

[2] 1 billion shares authorized; 571 million shares and 570 million shares outstanding at March 31, 2012 and December 31, 2011, respectively.

[3] Virginia Power’s Consolidated Balance Sheet at December 31, 2011 has been derived from the audited Consolidated Financial Statements at that date.

[4] 500,000 shares authorized; 274,723 shares outstanding at March 31, 2012 and December 31, 2011.

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Operating Revenue

3 Months Ended

Mar. 31, 2012

Regulated and Unregulated Operating Revenue [Abstract]

Operating Revenue

Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended March 31,
	2012		2011
(millions)
Dominion
Electric sales:
Regulated	$	1,724	$	1,730
Nonregulated	738		941
Gas sales:
Regulated	99		139
Nonregulated	398		602
Gas transportation and storage	405		538
Other	128		107
Total operating revenue	$	3,492	$	4,057
Virginia Power
Regulated electric sales	$	1,724	$	1,730
Other	30		27
Total operating revenue	$	1,754	$	1,757

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Significant Financing Transactions - (Narrative) (Details) (USD $)	3 Months Ended			1 Months Ended
	Mar. 31, 2012 Convertible Debt [Member]	Mar. 31, 2012 Convertible Debt [Member] Minimum	Mar. 31, 2012 Convertible Debt [Member] Maximum	Feb. 28, 2012 September 2006 hybrids [Member]	Mar. 31, 2012 September 2006 hybrids [Member]
Contingent convertible senior notes	$ 137,000,000
Conversion rate, shares of common stock per $1,000 principal amount of senior notes (in shares)	29.0360
Principal amount of senior notes	1,000
Conversion rate, shares of common stock per $1,000 principal amount of senior notes, conversion price	$ 34.44
Average Trading Price Principal Amount Of Senior Notes	120.00%
Minimum consecutive trading days		20 days
Maximum consecutive trading days			30 days
Debt Conversion, Converted Instrument, Amount	6,000,000
Tender Offer To Purchase Hybrid Subordinated Notes				150,000,000
Purchased And Cancelled Of Junior Subordinated Notes					$ 86,000,000

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2012

Earnings Per Share [Abstract]

Earnings Per Share Computation

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

	Three Months Ended March 31,
	2012		2011
(millions, except EPS)
Net income attributable to Dominion	$	494	$	479
Average shares of common stock outstanding – Basic	570.5		579.8
Net effect of potentially dilutive securities(1)	1.4		0.7
Average shares of common stock outstanding – Diluted	571.9		580.5
Earnings Per Common Share – Basic	$	0.87	$	0.83
Earnings Per Common Share – Diluted	$	0.86	$	0.82

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

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Income Taxes (Reconciliation of Income Taxes at the U.S. Statutory Federal Rate as Compared to the Income Tax Expense Recorded in Our Consolidated Statements of Income) (Details)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Income Tax Disclosure [Abstract]
U.S. statutory rate	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.80%	3.70%
Valuation allowances	(2.70%)	0.80%
AFUDC - equity	(0.70%)	(0.70%)
Other, net	(1.30%)	0.30%
Effective tax rate	34.10%	39.10%

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Credit Risk

3 Months Ended

Mar. 31, 2012

Risks and Uncertainties [Abstract]

Credit Risk

Credit Risk

Dominion’s and Virginia Power’s accounting policies for credit risk are discussed in Note 24 to the Consolidated Financial Statements in their Annual Report on Form 10-K for the year ended December 31, 2011.

At March 31, 2012, Dominion's gross credit exposure totaled $531 million. After the application of collateral, credit exposure was reduced to $461 million. Of this amount, investment grade counterparties, including those internally rated, represented 81%. One counterparty exposure represented 11% of Dominion's total exposure and is a large financial institution rated investment grade. At March 31, 2012, Virginia Power's exposure to potential concentrations of credit risk was not considered material.

Credit-Related Contingent Provisions

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 rating 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 March 31, 2012 and December 31, 2011, Dominion would have been required to post an additional $71 million and $88 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 $145 million in collateral, including $4 million of letters of credit, at March 31, 2012 and $110 million in collateral, including $4 million of letters of credit, at December 31, 2011, 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 March 31, 2012 and December 31, 2011 was $277 million and $259 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power were not material as of March 31, 2012 and December 31, 2011. See Note 7 for further information about derivative instruments.