Virginia Electric & Power 10-Q 5 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013
Entity Information [Line Items]	'
Document Type	'10-Q
Amendment Flag	'false
Document Period End Date	30-Sep-13
Document Fiscal Year Focus	'2013
Document Fiscal Period Focus	'Q3
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	580,435,589
Virginia Electric and Power Company	'
Entity Information [Line Items]	'
Document Type	'10-Q
Amendment Flag	'false
Document Period End Date	30-Sep-13
Document Fiscal Year Focus	'2013
Document Fiscal Period Focus	'Q3
Trading Symbol	'VEL - PE
Entity Registrant Name	'VIRGINIA ELECTRIC & POWER CO
Entity Central Index Key	'0000103682
Current Fiscal Year End Date	'--12-31
Entity Filer Category	'Non-accelerated Filer
Entity Common Stock, Shares Outstanding	274,723

Consolidated_Statements_of_Inc

Consolidated Statements of Income (USD $)	3 Months Ended				9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Operating Revenue	$3,432		$3,332	[1]	$9,935		$9,734	[2]
Operating Expenses	'		'		'		'
Electric fuel and other energy-related purchases	1,107		1,009	[1]	2,933		2,816	[2]
Purchased electric capacity	91		86	[1]	267		297	[2]
Purchased gas	232		191	[1]	996		818	[2]
Other operations and maintenance	525		1,086	[1]	1,876		2,446	[2]
Depreciation, depletion and amortization	309		290	[1]	909		838	[2]
Other taxes	134		119	[1]	442		422	[2]
Total operating expenses	2,398		2,781	[1]	7,423		7,637	[2]
Income from operations	1,034		551	[1]	2,512		2,097	[2]
Other income	86		56	[1]	222		174	[2]
Interest and related charges	217		197	[1]	648		618	[2]
Income from continuing operations including noncontrolling interests before income tax expense	903		410	[1]	2,086		1,653	[2]
Income tax expense	305		143	[1]	709		578	[2]
Income from continuing operations including noncontrolling interests	598		267	[1]	1,377		1,075	[2]
Loss from discontinued operations	-23	[3]	-52	[1],[3]	-92	[3]	-94	[2],[3]
Net Income Including Noncontrolling Interests	575		215	[2]	1,285		981	[2]
Noncontrolling Interests	6		6	[1]	19		20	[2]
Net Income Attributable to Dominion	569		209	[1],[2]	1,266		961	[2]
Amounts Attributable to Dominion:	'		'		'		'
Income from continuing operations, net of tax	592		261	[1]	1,358		1,055	[2]
Loss from discontinued operations, net of tax	-23		-52	[1]	-92		-94	[2]
Earnings Per Common Share-Basic	'		'		'		'
Income from continuing operations (dollars per share)	$1.02		$0.45	[1]	$2.35		$1.84	[2]
Loss from discontinued operations (dollars per share)	($0.04)		($0.09)	[1]	($0.16)		($0.16)	[2]
Earnings Per Common Share - Basic (dollars per share)	$0.98		$0.36	[1]	$2.19		$1.68	[2]
Earnings Per Common Share-Diluted	'		'		'		'
Income from continuing operations (dollars per share)	$1.02		$0.45	[1]	$2.35		$1.84	[2]
Loss from discontinued operations (dollars per share)	($0.04)		($0.09)	[1]	($0.16)		($0.16)	[2]
Net income attributable to Dominion (dollars per share)	$0.98		$0.36	[1]	$2.19		$1.68	[2]
Dividends declared per common share (dollars per share)	$0.56		$0.53	[1]	$1.69		$1.58	[2]
Income tax benefit from discontinued operations	6		17		43		53
Virginia Electric and Power Company	'		'		'		'
Operating Revenue	2,059		2,086		5,550		5,596
Operating Expenses	'		'		'		'
Electric fuel and other energy-related purchases	651		634		1,749		1,850
Purchased electric capacity	91		86		267		296
Affiliated suppliers	83		91		238		256
Other	273		278		792		861
Depreciation, depletion and amortization	218		203		636		579
Other taxes	64		48		196		179
Total operating expenses	1,380		1,340		3,878		4,021
Income from operations	679		746		1,672		1,575
Other income	19		25		71		65
Interest and related charges	93		97		270		297
Income from continuing operations including noncontrolling interests before income tax expense	605		674		1,473		1,343
Income tax expense	218		259		534		513
Net Income Attributable to Dominion	387		415		939		830
Amounts Attributable to Dominion:	'		'		'		'
Preferred dividends	4		4		12		12
Balance available for common stock	$383		$411		$927		$818
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
[2]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[3]	Includes income tax expense of $6 million for the three months ended September 30, 2013 and income tax benefit of $17 million, $43 million and $53 million for the three months ended September 30, 2012 and the nine months ended September 30, 2013 and 2012, respectively.

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Net income including noncontrolling interests	$575		$215	[1]	$1,285		$981	[1]
Net income	569		209	[1],[2]	1,266		961	[1]
Other comprehensive income (loss), net of taxes:	'		'		'		'
Net deferred gains (losses) on derivatives-hedging activities, net of tax	-77	[1]	-86	[1]	-45	[1]	40	[1]
Changes in unrealized net gains (losses) on investment securities	38	[3]	49	[3]	119	[3]	110	[3]
Changes in unrecognized pension and other postretirement benefit costs	-12	[4]	-6	[4]	216	[4]	-4	[4]
Amounts reclassified to net income:	'		'		'		'
Net derivative (gains) losses-hedging activities	-6	[5]	-20	[5]	53	[5]	-63	[5]
Net realized (gains) losses on investment securities	-10	[6]	-4	[6]	-46	[6]	-18	[6]
Net pension and other postretirement benefit costs	14	[7]	15	[7]	44	[7]	38	[7]
Total other comprehensive income (loss)	-53		-52		341		103
Comprehensive income including noncontrolling interests	522		163		1,626		1,084
Comprehensive income attributable to noncontrolling interests	6		6		19		20
Comprehensive income attributable to Dominion	516		157		1,607		1,064
Virginia Electric and Power Company	'		'		'		'
Net income	387		415		939		830
Other comprehensive income (loss), net of taxes:	'		'		'		'
Net deferred gains (losses) on derivatives-hedging activities, net of tax	1	[8]	-2	[8]	4	[8]	-5	[8]
Changes in unrealized net gains (losses) on investment securities	4	[9]	4	[9]	12	[9]	11	[9]
Amounts reclassified to net income:	'		'		'		'
Net derivative (gains) losses-hedging activities	1	[10]	1	[10]	0	[10]	2	[10]
Net realized (gains) losses on investment securities	-2	[11]	0	[11]	-2	[11]	-1	[11]
Total other comprehensive income (loss)	4		3		14		7
Comprehensive income attributable to Dominion	$391		$418		$953		$837
[1]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[2]	Recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
[3]	Net of $(29) million and $(33) million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $(80) million and $(73) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[4]	Net of $(12) million and $(7) million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $(160) million and $(8) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[5]	Net of $4 million and $12 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $(35) million and $39 million tax for the nine months ended September 30, 2013 and 2012, respectively
[6]	Net of $5 million and $3 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $28 million and $12 million tax for the nine months ended September 30, 2013 and 2012, respectively.
[7]	Net of $(9) million and $(6) million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $(29) million and $(23) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[8]	Net of $(1) million and $1 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $(3) million and $3 million tax for the nine months ended September 30, 2013 and 2012, respectively.
[9]	Net of $(2) million and $(4) million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $(7) million and $(7) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[10]	Net of $--- million and $--- million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $--- million and $(2) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[11]	Net of $--- million and $--- million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $1 million and $1 million tax for the nine months ended September 30, 2013 and 2012, respectively.

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Net deferred gains (losses) on derivative-hedging activities, tax	$43	$57	$21	($28)
Changes in unrealized net gains (losses) on investment securities, tax	-29	-33	-80	-73
Changes in unrecognized pension and other postretirement benefit costs, tax	-12	-7	-160	-8
Net derivative (gains) losses-hedging activities, tax	4	12	-35	39
Net realized (gains) losses on investment securities, tax	5	3	28	12
Net pension and other postretirement benefit costs, tax	-9	-6	-29	-23
Virginia Electric and Power Company	'	'	'	'
Net deferred gains (losses) on derivative-hedging activities, tax	-1	1	-3	3
Changes in unrealized net gains (losses) on investment securities, tax	-2	-4	-7	-7
Net derivative (gains) losses-hedging activities, tax	0	0	0	-2
Net realized (gains) losses on investment securities, tax	$0	$0	$1	$1

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets	'		'
Cash and cash equivalents	$287		$248	[1]
Customer receivables (less allowance for doubtful accounts)	1,499		1,621	[1]
Other receivables (less allowance for doubtful accounts)	103		96	[1]
Inventories	1,210		1,259	[1]
Derivative assets	689		518	[1]
Other	1,422		1,398	[1]
Total current assets	5,210		5,140	[1]
Investments	'		'
Nuclear decommissioning trust funds	3,673		3,330	[1]
Investment in equity method affiliates	926		558	[1]
Other	277		303	[1]
Total investments	4,876		4,191	[1]
Property, Plant and Equipment	'		'
Property, plant and equipment	46,102		43,364	[1]
Property, plant and equipment, VIE	0		957	[1]
Accumulated depreciation, depletion and amortization	-14,241		-13,548	[1]
Total property, plant and equipment, net	31,861		30,773	[1]
Deferred Charges and Other Assets	'		'
Goodwill	3,087	[2]	3,130	[1],[2]
Regulatory assets	1,478		1,717	[1]
Other	1,976		1,887	[1]
Total deferred charges and other assets	6,541		6,734	[1]
Total assets	48,488		46,838	[1]
Current Liabilities	'		'
Securities due within one year	1,132		1,363	[1]
Securities due within one year, VIE	0		860	[1]
Short-term debt	2,145		2,412	[1]
Accounts payable	980		1,137	[1]
Derivative liabilities	659		510	[1]
Other	1,537		1,481	[1]
Total current liabilities	6,453		7,763	[1]
Long-Term Debt	'		'
Long-term debt	16,096		15,478	[1]
Junior subordinated notes	1,373		1,373	[1]
Remarketable subordinated notes	1,079		0	[1]
Total long-term debt	18,548		16,851	[1]
Deferred Credits and Other Liabilities	'		'
Deferred income taxes and investment tax credits	6,735		5,800	[1]
Asset retirement obligations	1,625		1,641	[1]
Pension and other postretirement benefit liabilities	1,294		1,831	[1]
Regulatory liabilities	1,718		1,514	[1]
Other	616		556	[1]
Total deferred credits and other liabilities	11,988		11,342	[1]
Total liabilities	36,989		35,956	[1]
Subsidiary Preferred Stock Not Subject to Mandatory Redemption	257		257	[1]
Equity	'		'
Common stock - no par	5,699	[3]	5,493	[1],[3]
Other paid-in capital	0		162	[1]
Retained earnings	6,079		5,790	[1]
Accumulated other comprehensive loss	-536		-877	[1]
Total common shareholders’ equity	11,242		10,568	[1]
Noncontrolling interest	0		57	[1]
Total equity	11,242		10,625	[1]
Total liabilities and equity	48,488		46,838	[1]
Virginia Electric and Power Company	'		'
Current Assets	'		'
Cash and cash equivalents	51		28	[4]
Customer receivables (less allowance for doubtful accounts)	906		849	[4]
Other receivables (less allowance for doubtful accounts)	59		51	[4]
Inventories	804		789	[4]
Prepayments	28		23	[4]
Other	271		241	[4]
Total current assets	2,119		1,981	[4]
Investments	'		'
Nuclear decommissioning trust funds	1,668		1,515	[4]
Other	14		14	[4]
Total investments	1,682		1,529	[4]
Property, Plant and Equipment	'		'
Property, plant and equipment	32,249		30,631	[4]
Accumulated depreciation, depletion and amortization	-10,481		-10,014	[4]
Total property, plant and equipment, net	21,768		20,617	[4]
Deferred Charges and Other Assets	'		'
Intangible assets, net	187		181	[4]
Regulatory assets	420		396	[4]
Other	134		107	[4]
Total deferred charges and other assets	741		684	[4]
Total assets	26,310		24,811	[4]
Current Liabilities	'		'
Securities due within one year	58		418	[4]
Short-term debt	485		992	[4]
Accounts payable	392		430	[4]
Payables to affiliates	87		67	[4]
Affiliated current borrowings	0		435	[4]
Accrued interest, payroll and taxes	354		204	[4]
Other	413		461	[4]
Total current liabilities	1,789		3,007	[4]
Long-Term Debt	'		'
Total long-term debt	7,981		6,251	[4]
Deferred Credits and Other Liabilities	'		'
Deferred income taxes and investment tax credits	4,112		3,879	[4]
Asset retirement obligations	727		705	[4]
Regulatory liabilities	1,471		1,285	[4]
Other	263		194	[4]
Total deferred credits and other liabilities	6,573		6,063	[4]
Total liabilities	16,343		15,321	[4]
Subsidiary Preferred Stock Not Subject to Mandatory Redemption	257		257	[4]
Equity	'		'
Common stock - no par	5,738	[5]	5,738	[4],[5]
Other paid-in capital	1,113		1,113	[4]
Retained earnings	2,820		2,357	[4]
Accumulated other comprehensive loss	39		25	[4]
Total common shareholders’ equity	9,710		9,233	[4]
Total liabilities and equity	$26,310		$24,811	[4]
[1]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[2]	Goodwill amounts do not contain any accumulated impairment losses.
[3]	1 billion shares authorized; 580 million shares and 576 million shares outstanding at September 30, 2013 and December 31, 2012, respectively.
[4]	Virginia Power’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[5]	500,000 shares authorized; 274,723 shares outstanding at September 30, 2013 and December 31, 2012.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Customer receivables, allowance for doubtful accounts	$27	$28
Other receivables, allowance for doubtful accounts	3	4
Common stock, shares authorized (shares)	1,000,000,000	'
Common stock, shares outstanding (shares)	580,000,000	576,000,000
Virginia Electric and Power Company	'	'
Customer receivables, allowance for doubtful accounts	10	10
Other receivables, allowance for doubtful accounts	$2	$3
Common stock, shares authorized (shares)	500,000	'
Common stock, shares outstanding (shares)	274,723	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012
Operating Activities	'		'
Net income including noncontrolling interests	$1,285		$981	[1]
Net income	1,266		961	[1]
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:	'		'
Impairment of merchant generation assets	48		444
Gains on sales of assets	-118		0
Depreciation, depletion and amortization (including nuclear fuel)	1,104		1,080
Deferred income taxes and investment tax credits	601		550
Rate refunds	-5		-132
Other adjustments	-79		-91
Changes in:	'		'
Accounts receivable	98		371
Inventories	-63		35
Deferred fuel and purchased gas costs, net	85		332
Prepayments	46		-72
Accounts payable	-144		-216
Accrued interest, payroll and taxes	-38		1
Margin deposit assets and liabilities	-27		126
Other operating assets and liabilities	157		53
Net cash provided by operating activities	2,950		3,462
Investing Activities	'		'
Plant construction and other property additions (including nuclear fuel)	-2,978		-2,884
Proceeds from sales of assets	595		0
Proceeds from sales of securities	1,260		1,040
Purchases of securities	-1,278		-1,047
Restricted cash equivalents	23		92
Other	30		15
Net cash used in investing activities	-2,348		-2,784
Financing Activities	'		'
Repayment of short-term debt, net	-267		-433
Issuance of long-term debt	2,935		1,500
Repayment of long-term debt, including redemption premiums	-1,214		-1,037
Repayment of junior subordinated notes	-258		0
Acquisition of Juniper noncontrolling interest in Fairless	-923		0
Issuance of common stock	206		197
Common dividend payments	-976		-906
Subsidiary preferred dividend payments	-12		-12
Other	-54		-8
Net cash used in financing activities	-563		-699
Increase (decrease) in cash and cash equivalents	39		-21
Cash and cash equivalents at beginning of period	248	[2]	102
Cash and cash equivalents at end of period	287		81
Significant noncash investing activities:	'		'
Contribution of assets in exchange for additional ownership interest in Blue Racer	271		328
Contribution of assets in exchange for additional ownership interest in Blue Racer	473		0
Virginia Electric and Power Company	'		'
Operating Activities	'		'
Net income	939		830
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:	'		'
Depreciation, depletion and amortization (including nuclear fuel)	758		687
Deferred income taxes and investment tax credits	243		331
Rate refunds	-5		-132
Other adjustments	-49		-47
Changes in:	'		'
Accounts receivable	-65		-2
Affiliated accounts payable	20		40
Inventories	-15		40
Deferred fuel and purchased gas costs, net	47		321
Accounts payable	-10		28
Accrued interest, payroll and taxes	150		70
Other operating assets and liabilities	23		121
Net cash provided by operating activities	2,036		2,287
Investing Activities	'		'
Plant construction and other property additions (including nuclear fuel)	-1,794		-1,402
Purchases of nuclear fuel	-108		-142
Proceeds from sales of securities	464		481
Purchases of securities	-501		-491
Restricted cash equivalents	0		21
Other	-9		-18
Net cash used in investing activities	-1,948		-1,551
Financing Activities	'		'
Repayment of short-term debt, net	-507		-789
Repayment of affiliated current borrowings, net	-435		0
Issuance of long-term debt	1,835		450
Repayment of long-term debt, including redemption premiums	-462		-10
Common dividend payments	-463		-379
Subsidiary preferred dividend payments	-12		-12
Other	-21		-4
Net cash used in financing activities	-65		-744
Increase (decrease) in cash and cash equivalents	23		-8
Cash and cash equivalents at beginning of period	28	[3]	29
Cash and cash equivalents at end of period	51		21
Significant noncash investing activities:	'		'
Contribution of assets in exchange for additional ownership interest in Blue Racer	$137		$136
[1]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[2]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[3]	Virginia Power’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.

Nature_of_Operations

Nature of Operations	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [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.

Significant_Accounting_Policie

Significant Accounting Policies	9 Months Ended
	Sep. 30, 2013
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, 2012 and their Quarterly Reports on Form 10-Q for the quarters ended March 31, 2013 and June 30, 2013.
	In Dominion’s and Virginia Power’s opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position as of September 30, 2013, their results of operations for the three and nine months ended September 30, 2013 and 2012 and their cash flows for the nine months ended September 30, 2013 and 2012. 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 2012 Consolidated Financial Statements and Notes have been reclassified to conform to the 2013 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.

Dispositions

Dispositions	9 Months Ended
	Sep. 30, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Dispositions	'
	Dispositions
	Sale of Illinois Gas Contracts
	In June 2013, Dominion completed the sale of Illinois Gas Contracts. The sales price was approximately $32 million, subject to post-closing adjustments. The sale resulted in a gain of approximately $29 million ($18 million after-tax) net of a $3 million write-off of goodwill, and is included in other operations and maintenance expense in Dominion's Consolidated Statement of Income. The sale of Illinois Gas Contracts did not qualify for discontinued operations classification as it is not considered a component under applicable accounting guidance.
	Sale of Brayton Point, Kincaid and Equity Method Investment in Elwood
	In March 2013, Dominion entered into an agreement with Energy Capital Partners to sell Brayton Point, Kincaid, and its equity method investment in Elwood.
	In the first and second quarters of 2013, Brayton Point's and Kincaid's assets and liabilities to be disposed of were classified as held for sale and adjusted to their estimated fair value less cost to sell, resulting in impairment charges totaling $48 million ($28 million after-tax), which are included in discontinued operations in Dominion's Consolidated Statements of Income. In both periods, Dominion used the market approach to estimate the fair value of Brayton Point's and Kincaid's long-lived assets. These were considered Level 2 fair value measurements given that they were based on the agreed-upon sales price.
	Dominion's 50% interest in Elwood was an equity method investment and therefore, in accordance with applicable accounting guidance, the carrying amount of this investment was not classified as held for sale nor were the equity earnings from this investment reported as discontinued operations.
	In August 2013, Dominion completed the sale and received proceeds of approximately $465 million, net of transaction costs. The sale resulted in a $35 million ($25 million after-tax) gain attributable to its equity method investment in Elwood, which is included in other income in Dominion's Consolidated Statement of Income, which was partially offset by a $17 million ($18 million after-tax) loss attributable to Brayton Point and Kincaid, which includes a $16 million write-off of goodwill and is reflected in loss from discontinued operations in Dominion's Consolidated Statement of Income.
	The following table presents selected information regarding the results of operations of Brayton Point and Kincaid, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013				2012
	(millions)
	Operating revenue	$	87		$	77		$	304			$	191
	Loss before income taxes	(17		)	(50		)	(135		)	(1)	(98		)
	-1	Includes $64 million of charges related to the early redemption of Brayton Point and Kincaid debt. See Note 14 in this report for more information.
	Sale of Salem Harbor and State Line
	In the third quarter of 2012, Dominion completed the sale of Salem Harbor. During the second quarter of 2012, Dominion completed the sale of State Line, which ceased operations in March 2012.
	The following table presents selected information regarding the results of operations of Salem Harbor and State Line, which are classified in discontinued operations in Dominion's Consolidated Statements of Income:
		Three Months Ended September 30, 2012			Nine Months Ended September 30, 2012
	(millions)
	Operating revenue	$	5		$	57
	Loss before income taxes	(19		)	(49		)

Operating_Revenue

Operating Revenue	9 Months Ended
	Sep. 30, 2013
Regulated and Unregulated Operating Revenue [Abstract]	'
Operating Revenue	'
	Operating Revenue
	The Companies’ operating revenue consists of the following:
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
	(millions)
	Dominion
	Electric sales:
	Regulated	$	2,023	$	2,046	$	5,471	$	5,495
	Nonregulated	704		661		1,907		1,930
	Gas sales:
	Regulated	32		34		213		166
	Nonregulated	159		177		712		740
	Gas transportation and storage	329		297		1,156		1,007
	Other	185		117		476		396
	Total operating revenue	$	3,432	$	3,332	$	9,935	$	9,734
	Virginia Power
	Regulated electric sales	$	2,023	$	2,046	$	5,471	$	5,495
	Other	36		40		79		101
	Total operating revenue	$	2,059	$	2,086	$	5,550	$	5,596

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	In December 2011, the IRS issued temporary regulations that provide guidance to taxpayers on the treatment of amounts paid to acquire, produce or improve tangible property and of dispositions of such property, including whether expenditures should be deducted as repairs or capitalized and depreciated on tax returns. Upon issuance, the temporary regulations were generally to be effective for expenditures made on or after January 1, 2012. However, in December 2012, in response to public comments received, the IRS amended the temporary regulations to postpone the effective date until January 1, 2014.
	In September 2013, the IRS withdrew the December 2011 temporary regulations and issued final regulations. The final regulations include a number of safe harbor tax accounting methods which a taxpayer may choose to elect and, if adopted, will not be challenged by the IRS. In addition, the IRS reissued certain temporary regulations that were also issued concurrently as proposed regulations regarding property dispositions. The final regulations are effective for tax years beginning on or after January 1, 2014.  Although changes in tax accounting methods would be effective prospectively, implementation of certain changes will require a calculation of the cumulative effect of the change on prior years. Beginning with the year of the change, this cumulative effect is includible in taxable income over a period assumed to be four years, pending the issuance of IRS procedural guidance.
	Dominion and Virginia Power have evaluated tax accounting method changes that may be elected or required by the final regulations. At September 30, 2013, $13 million of deferred tax liabilities have been classified as current in the Companies’ Consolidated Balance Sheets, representing cumulative adjustment amounts expected to be reflected in income for tax purposes during the nine months ending September 30, 2014. Tax accounting method changes in 2014 are not expected to materially affect the Companies’ cash flows, results of operations or financial condition.
	For continuing operations, including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to Dominion's and Virginia Power’s effective income tax rate as follows:
		Dominion				Virginia Power
	Nine Months Ended September 30,	2013		2012		2013		2012
	U.S. statutory rate	35	%	35	%	35	%	35	%
	Increases (reductions) resulting from:
	State taxes, net of federal benefit	2.4		4.4		2.8		3.9
	Investment and production tax credits	(1.8	)	(0.6	)	(0.2	)	—
	Valuation allowances	—		(0.9	)	—		—
	AFUDC - equity	(0.7	)	(0.9	)	(1.1	)	(0.8	)
	Other, net	(0.9	)	(2.1	)	(0.3	)	0.1
	Effective tax rate	34	%	34.9	%	36.2	%	38.2	%
	Dominion's and Virginia Power's 2013 state income tax expense reflects changes in the amount of income apportioned among states.
	Dominion's effective tax rate in 2012 reflects a $20 million reduction of valuation allowance related to state operating loss carryforwards attributable to Fairless. After considering the results of Fairless’ operations in recent years and a forecast of future operating results reflecting Dominion’s planned purchase of the facility, Dominion concluded that it was more likely than not that the tax benefit of the operating losses would be realized. Significant assumptions included 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 would significantly influence the extent to which Fairless is dispatched by PJM. In August 2013, Dominion purchased Fairless from Juniper per the terms of the lease agreement. See Note 13 in this report for more information.
	See Note 5 to the Consolidated Financial Statements in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2012, for a discussion of the Companies' unrecognized tax benefits. During the nine months ended September 30, 2013, Dominion's and Virginia Power's unrecognized tax benefits changed as follows:
		Dominion		Virginia Power
	(millions)
	Balance at January 1, 2013	$293		$57
	Increases - prior period positions	14		12
	Decreases - prior period positions	(91	)	(42	)
	Current period positions	21		7
	Settlements	(2	)	(2	)
	Expiration of statutes of limitations	(4	)	—
	Balance at September 30, 2013	$231		$32
	Discontinued Operations
	Dominion's effective tax rate for 2013 reflects the impact of goodwill written off in the sale of Kincaid and Brayton Point that is not deductible for tax purposes.

Earnings_Per_Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2013
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 September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
	(millions, except EPS)
	Net income attributable to Dominion	$	569	$	209	$	1,266	$	961
	Average shares of common stock outstanding – Basic	579.4		573.8		578.1		572.1
	Net effect of dilutive securities(1)	0.7		0.9		0.7		1.1
	Average shares of common stock outstanding – Diluted	580.1		574.7		578.8		573.2
	Earnings Per Common Share – Basic	$	0.98	$	0.36	$	2.19	$	1.68
	Earnings Per Common Share – Diluted	$	0.98	$	0.36	$	2.19	$	1.68
	-1	Dilutive securities consist primarily of contingently convertible senior notes. See Note 14 in this report for more information.
	Dominion's 2013 Series A Equity Units and 2013 Series B Equity Units issued in June 2013 are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three and nine months ended September 30, 2013.  See Note 14 in this report for more information. There were no potentially dilutive securities excluded from the calculation of diluted EPS for the three and nine months ended September 30, 2012.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Accumulated Other Comprehensive Income	'
	Accumulated Other Comprehensive Income
	The following table presents Dominion’s changes in AOCI by component, net of tax:
		Deferred gains and losses on derivatives-hedging activities			Unrealized gains and losses on investment securities			Unrecognized pension and other postretirement benefit costs			Total
	(millions)
	Three Months Ended September 30, 2013
	Beginning balance	$	(31	)	$	371		$	(823	)	$	(483	)
	Other comprehensive income before reclassifications: gains (losses)	(77		)	38			(12		)	(51		)
	Amounts reclassified from accumulated other comprehensive income(1): (gains) losses	(6		)	(10		)	14			(2		)
	Net current-period other comprehensive income (loss)	(83		)	28			2			(53		)
	Ending balance	$	(114	)	$	399		$	(821	)	$	(536	)
	Nine Months Ended September 30, 2013
	Beginning balance	$	(122	)	$	326		$	(1,081	)	$	(877	)
	Other comprehensive income before reclassifications: gains (losses)	(45		)	119			216			290
	Amounts reclassified from accumulated other comprehensive income(1): (gains) losses	53			(46		)	44			51
	Net current-period other comprehensive income (loss)	8			73			260			341
	Ending balance	$	(114	)	$	399		$	(821	)	$	(536	)
	(1) See table below for details about these reclassifications.
	The following table presents Dominion’s reclassifications out of AOCI by component:
	Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
	(millions)
	Three Months Ended September 30, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	(24	)	Operating revenue
		5			Purchased gas
		3			Electric fuel and other energy-related purchases
	Interest rate contracts	6			Interest and related charges
		(10		)
	Tax	4			Income tax expense
		$	(6	)
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(16	)	Other income
	Impairment	1			Other income
		(15		)
	Tax	5			Income tax expense
		$	(10	)
	Unrecognized pension and other postretirement benefit costs:
	Actuarial losses	$	23		Other operations and maintenance
		23
	Tax	(9		)	Income tax expense
		$	14
	Nine Months Ended September 30, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	31		Operating revenue
		39			Purchased gas
		6			Electric fuel and other energy-related purchases
	Interest rate contracts	12			Interest and related charges
		88
	Tax	(35		)	Income tax expense
		$	53
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(80	)	Other income
	Impairment	6			Other income
		(74		)
	Tax	28			Income tax expense
		$	(46	)
	Unrecognized pension and other postretirement benefit costs:
	Prior service costs	$	(6	)	Other operations and maintenance
	Actuarial losses	79			Other operations and maintenance
		73
	Tax	(29		)	Income tax expense
		$	44

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
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 6 to the Consolidated Financial Statements in their Annual Report on Form 10-K for the year ended December 31, 2012. See Note 9 in this report for further information about their derivatives and hedge accounting activities.
	Dominion and Virginia Power enter into certain physical and financial forwards and futures, options, and full requirements contracts, which are considered Level 3 as they have one or more inputs that are not observable and are significant to the valuation. The discounted cash flow method is used to value Level 3 physical and financial forwards, futures, and full requirements contracts. An option model is used to value Level 3 physical and financial options. The discounted cash flow model for forwards and futures calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. Full requirements contracts add load shaping and usage factors in addition to the discounted cash flow model inputs. 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, mean reversions, 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, forward market prices, implied price volatilities, price correlations, load shaping, and usage factors 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 and Virginia Power's quantitative information about Level 3 fair value measurements. The range and weighted average are presented in dollars for market price inputs, years for mean reversion speeds, and percentages for price volatility, price correlations, load shaping, and usage factors.
		Fair Value (millions)			Valuation Techniques	Unobservable Input		Range	Weighted Average(1)
	At September 30, 2013
	Assets:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	10		Discounted Cash Flow	Market Price (per Dth)	(4)	(1) - 5	2
	Electricity	9			Discounted Cash Flow	Market Price (per MWh)	(4)	31 - 77	44
	FTRs(3)	1			Discounted Cash Flow	Market Price (per MWh)	(4)	(1) - 6	0
	Liquids	12			Discounted Cash Flow	Market Price (per Gal)	(4)	0 - 3	1
	Physical and Financial Options:
	Natural Gas	7			Option Model	Market Price (per Dth)	(4)	5-Mar	4
						Price Volatility	(5)	19% - 30%	24	%
						Price Correlation	(6)	(9)% - 100%	36	%
						Mean Reversion	(7)	0 - 58	4
	Full Requirements Contracts:
	Electricity	13			Discounted Cash Flow	Market Price (per MWh)	(4)	10 - 403(10)	34
						Load Shaping	(8)	0% - 10%	7	%
						Usage Factor	(9)	11% - 15%	14	%
	Total assets	$	52
	Liabilities:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	16		Discounted Cash Flow	Market Price (per Dth)	(4)	(1) - 5	1
	Electricity	6			Discounted Cash Flow	Market Price (per MWh)	(4)	23 - 86	50
	FTRs(3)	16			Discounted Cash Flow	Market Price (per MWh)	(4)	(4) - 6	1
	Liquids	8			Discounted Cash Flow	Market Price (per Gal)	(4)	3-Jan	2
	Physical and Financial Options:
	Natural Gas	10			Option Model	Market Price (per Dth)	(4)	10-Mar	5
						Price Volatility	(5)	19% - 30%	23	%
						Price Correlation	(6)	(9)% - 100%	36	%
						Mean Reversion	(7)	0 - 58	4
	Total liabilities	$	56
	-1	Averages weighted by volume.
	-2	Includes basis.
	-3	Information represents Virginia Power's quantitative information about Level 3 fair value measurements.
	-4	Represents market prices beyond defined terms for Levels 1 & 2.
	-5	Represents volatilities unrepresented in published markets.
	-6	Represents intra-price correlations for which markets do not exist.
	-7	Represents mean-reverting property in price simulation modeling.
	-8	Converts block monthly loads to 24-hour load shapes.
	-9	Represents expected increase (decrease) in sales volumes compared to historical usage.
	-10	The range in market prices is the result of large variability in hourly power prices during peak and off-peak hours.
	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)
	Mean Reversion	Buy	Increase (decrease)	Loss (gain)
	Mean Reversion	Sell	Increase (decrease)	Gain (loss)
	Load Shaping	Sell(1)	Increase (decrease)	Loss (gain)
	Usage Factor	Sell(2)	Increase (decrease)	Gain (loss)
	-1	Assumes the contract is in a gain position and load increases during peak hours.
	-2	Assumes the contract is in a gain position.
	Non-recurring Fair Value Measurements
	In June 2013, Dominion purchased certain natural gas infrastructure facilities that were previously leased from third parties. The purchase price was based on terms in the lease, which exceeded current market pricing. As a result of the purchase price and expected losses, Dominion recorded an impairment charge of $49 million ($29 million after-tax) in other operations and maintenance expense in its Consolidated Statements of Income, to write down the long-lived assets to their estimated fair values 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 the assets in this impairment test. This was considered a Level 3 fair value measurement due to the use of significant unobservable inputs, including estimates of future production and other commodity prices.
	See Note 3 for non-recurring fair value measurements related to Brayton Point and Kincaid.
	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 September 30, 2013
Assets:
Derivatives:
Commodity	$	6		$	713		$	52		$	771
Interest rate	—			114			—			114
Investments(1):
Equity securities:
U.S.:
Large cap	2,211			—			—			2,211
Other	74			—			—			74
Non-U.S.:
Large cap	11			—			—			11
Fixed income:
Corporate debt instruments	—			352			—			352
U.S. Treasury securities and agency debentures	414			168			—			582
State and municipal	—			342			—			342
Other	—			4			—			4
Cash equivalents and other	9			80			—			89
Restricted cash equivalents	—			10			—			10
Total assets	$	2,725		$	1,783		$	52		$	4,560
Liabilities:
Derivatives:
Commodity	$	5		$	721		$	56		$	782
Interest rate	—			11			—			11
Total liabilities	$	5		$	732		$	56		$	793
At December 31, 2012
Assets:
Derivatives:
Commodity	$	12		$	639		$	84		$	735
Interest rate	—			93			—			93
Investments(1):
Equity securities:
U.S.:
Large cap	1,973			—			—			1,973
Other	59			—			—			59
Non-U.S.:
Large cap	12			—			—			12
Fixed income:
Corporate debt instruments	—			325			—			325
U.S. Treasury securities and agency debentures	391			152			—			543
State and municipal	—			315			—			315
Other	—			7			—			7
Cash equivalents and other	13			67			—			80
Restricted cash equivalents	—			33			—			33
Total assets	$	2,460		$	1,631		$	84		$	4,175
Liabilities:
Derivatives:
Commodity	$	8		$	528		$	59		$	595
Interest rate	—			66			—			66
Total liabilities	$	8		$	594		$	59		$	661
-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 September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
(millions)
Beginning balance	$	2		$	155		$	25		$	(71	)
Total realized and unrealized gains (losses):
Included in earnings	(1		)	(8		)	1			(31		)
Included in other comprehensive income (loss)	(25		)	(48		)	11			124
Included in regulatory assets/liabilities	10			2			(17		)	30
Settlements	3			3			(23		)	54
Transfers out of Level 3	7			(1		)	(1		)	(3		)
Ending balance	$	(4	)	$	103		$	(4	)	$	103
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	$	2		$	(15	)	$	—		$	25
The following table presents Dominion's classification of gains and losses included in earnings in the Level 3 fair value category:
	Operating			Electric fuel			Total
	revenue			and other
				energy-related
				purchases
(millions)
Three Months Ended September 30, 2013
Total gains (losses) included in earnings	$	5		$	(6	)	$	(1	)
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	2			—			2
Three Months Ended September 30, 2012
Total gains (losses) included in earnings	$	(10	)	$	2		$	(8	)
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	(15		)	—			(15		)
Nine Months Ended September 30, 2013
Total gains (losses) included in earnings	$	12		$	(11	)	$	1
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	—			—			—
Nine Months Ended September 30, 2012
Total gains (losses) included in earnings	$	13		$	(44	)	$	(31	)
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	25			—			25
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 September 30, 2013
Assets:
Derivatives:
Commodity	$	—		$	1		$	1		$	2
Interest rate	—			33			—			33
Investments(1):
Equity securities:
U.S.:
Large cap	939			—			—			939
Other	33			—			—			33
Fixed income:
Corporate debt instruments	—			197			—			197
U.S. Treasury securities and agency debentures	146			63			—			209
State and municipal	—			160			—			160
Cash equivalents and other	—			24			—			24
Restricted cash equivalents	—			10			—			10
Total assets	$	1,118		$	488		$	1		$	1,607
Liabilities:
Derivatives:
Commodity	$	—		$	4		$	16		$	20
Total liabilities	$	—		$	4		$	16		$	20
At December 31, 2012
Assets:
Derivatives:
Commodity	$	—		$	1		$	5		$	6
Investments(1):
Equity securities:
U.S.:
Large cap	779			—			—			779
Other	27			—			—			27
Fixed income:
Corporate debt instruments	—			196			—			196
U.S. Treasury securities and agency debentures	168			66			—			234
State and municipal	—			118			—			118
Other	—			1			—			1
Cash equivalents and other	7			31			—			38
Restricted cash equivalents	—			10			—			10
Total assets	$	981		$	423		$	5		$	1,409
Liabilities:
Derivatives:
Commodity	$	—		$	6		$	3		$	9
Interest rate	—			25			—			25
Total liabilities	$	—		$	31		$	3		$	34
-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 September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
(millions)
Beginning balance	$	(25	)	$	1		$	2		$	(28	)
Total realized and unrealized gains (losses):
Included in earnings	(4		)	2			(9		)	(44		)
Included in regulatory assets/liabilities	10			2			(17		)	31
Settlements	4			(2		)	9			44
Ending balance	$	(15	)	$	3		$	(15	)	$	3
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 and nine months ended September 30, 2013 and 2012. There were no unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the three and nine months ended September 30, 2013 and 2012.
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, which 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:
	30-Sep-13						31-Dec-12
	Carrying			Estimated Fair			Carrying			Estimated Fair
	Amount			Value(1)			Amount			Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	17,228		$	18,899		$	16,841		$	19,898
Securities due within one year, VIE(3)	—			—			860			864
Junior subordinated notes(3)	1,373			1,397			1,373			1,430
Remarketable subordinated notes(3)	1,079			1,175			—			—
Subsidiary preferred stock(4)	257			258			257			255
Virginia Power
Long-term debt, including securities due within one year(2)	$	8,039		$	8,975		$	6,669		$	8,270
Preferred stock(4)	257			258			257			255
-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	Carrying amount includes amounts which represent the unamortized discount and premium. At September 30, 2013 and December 31, 2012, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $56 million and $93 million, respectively.
-3	Carrying amount includes amounts which represent the unamortized discount or premium.
-4	Carrying amount includes deferred issuance expenses of $2 million at September 30, 2013 and December 31, 2012.

Derivatives_and_Hedge_Accounti

Derivatives and Hedge Accounting Activities	9 Months Ended
	Sep. 30, 2013
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, 2012. See Note 8 in this report for further information about fair value measurements and associated valuation methods for derivatives.
	Derivative assets and liabilities are presented gross on Dominion's and Virginia Power's Consolidated Balance Sheets. Dominion's and Virginia Power's derivative contracts include both over-the-counter transactions and those that are executed on an exchange or other trading platform (exchange contracts) and centrally cleared. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Exchange contracts utilize a financial intermediary, exchange, or clearinghouse to enter, execute, or clear the transactions. Certain over-the-counter and exchange contracts contain contractual rights of setoff through master netting arrangements, derivative clearing agreements, and contract default provisions. In addition, the contracts are subject to conditional rights of setoff through counterparty nonperformance, insolvency, or other conditions.
	In general, most over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral for over-the-counter and exchange contracts include cash, letters of credit, and in some cases other forms of security, none of which are subject to restrictions. Cash collateral is used in the table below to offset derivative assets and liabilities. Certain accounts receivable and accounts payable recognized on Dominion's and Virginia Power's Consolidated Balance Sheets, as well as letters of credit and other forms of security, all of which are not included in the tables below, are subject to offset under master netting or similar arrangements and would reduce the net exposure.
	Dominion
	The tables below present Dominion's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
		30-Sep-13									31-Dec-12
		Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	114		$	—		$	114		$	93		$	—	$	93
	Commodity contracts:
	Over-the-counter	190			—			190			290			—		290
	Exchange	568			—			568			416			—		416
	Total derivatives, subject to a master netting or similar arrangement	872			—			872			799			—		799
	Total derivatives, not subject to a master netting or similar arrangement	13			—			13			29			—		29
	Total(1)	$	885		$	—		$	885		$	828		$	—	$	828
	-1	At September 30, 2013, the total derivative asset balance contains $689 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $196 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.
					30-Sep-13											31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts			Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	114		$	11		$	—		$	103		$	93	$	19	$	—	$	74
	Commodity contracts:
	Over-the-counter	190			78			—			112			290		97		—		193
	Exchange	568			563			3			2			416		350		4		62
	Total	$	872		$	652		$	3		$	217		$	799	$	466	$	4	$	329
		30-Sep-13									31-Dec-12
		Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	11		$	—		$	11		$	66		$	—	$	66
	Commodity contracts:
	Over-the-counter	162			—			162			191			—		191
	Exchange	617			—			617			393			—		393
	Total derivatives, subject to a master netting or similar arrangement	790			—			790			650			—		650
	Total derivatives, not subject to a master netting or similar arrangement	3			—			3			11			—		11
	Total(1)	$	793		$	—		$	793		$	661		$	—	$	661
	-1	At September 30, 2013, the total derivative liability balance contains $659 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $134 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.
					30-Sep-13											31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Paid			Net Amounts			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	11		$	11		$	—		$	—		$	66	$	19	$	—	$	47
	Commodity contracts:
	Over-the-counter	162			78			17			67			191		97		20		74
	Exchange	617			563			54			—			393		350		43		—
	Total	$	790		$	652		$	71		$	67		$	650	$	466	$	63	$	121
	The following table presents the volume of Dominion’s derivative activity as of September 30, 2013. 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)	149			27
	Basis	529			379
	Electricity (MWh):
	Fixed price(1)	17,059,889			15,411,998
	FTRs	64,859,720			689,289
	Capacity (MW)	133,650			18,300
	Liquids (Gal)(2)	152,418,000			35,700,000
	Interest rate	$	2,400,000,000		$	1,150,000,000
	-1	Includes options.
	-2	Includes NGLs and oil.
For the three and nine months ended September 30, 2013 and 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 September 30, 2013:
	AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum Term
	After-Tax
(millions)
Commodities:
Gas	$	(7	)	$	(6	)	31 months
Electricity	6			(9		)	39 months
Other	4			2			32 months
Interest rate	(117		)	(21		)	367 months
Total	$	(114	)	$	(34	)
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 –			Fair Value –			Total Fair Value
	Derivatives under			Derivatives not under
	Hedge			Hedge
	Accounting			Accounting
(millions)
30-Sep-13
ASSETS
Current Assets
Commodity	$	53		$	546		$	599
Interest rate	90			—			90
Total current derivative assets	143			546			689
Noncurrent Assets
Commodity	70			102			172
Interest rate	24			—			24
Total noncurrent derivative assets(1)	94			102			196
Total derivative assets	$	237		$	648		$	885
LIABILITIES
Current Liabilities
Commodity	$	64		$	584		$	648
Interest rate	11			—			11
Total current derivative liabilities	75			584			659
Noncurrent Liabilities
Commodity	47			87			134
Total noncurrent derivative liabilities(2)	47			87			134
Total derivative liabilities	$	122		$	671		$	793
31-Dec-12
ASSETS
Current Assets
Commodity	$	103		$	379		$	482
Interest rate	36			—			36
Total current derivative assets	139			379			518
Noncurrent Assets
Commodity	130			123			253
Interest rate	57			—			57
Total noncurrent derivative assets(1)	187			123			310
Total derivative assets	$	326		$	502		$	828
LIABILITIES
Current Liabilities
Commodity	$	103		$	341		$	444
Interest rate	66			—			66
Total current derivative liabilities	169			341			510
Noncurrent Liabilities
Commodity	58			93			151
Total noncurrent derivative liabilities(2)	58			93			151
Total derivative liabilities	$	227		$	434		$	661
-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			Amount of Gain			Increase
	(Loss)			(Loss) Reclassified			(Decrease) in
	Recognized			from AOCI to			Derivatives
	in AOCI  on			Income			Subject to
	Derivatives						Regulatory
	(Effective						Treatment(2)
	Portion)(1)
(millions)
Three Months Ended September 30, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	24
Purchased Gas				(5		)
Electric fuel and other energy-related purchases				(3		)
Total commodity	$	(110	)	$	16		$	4
Interest rate(3)	(10		)	(6		)	14
Total	$	(120	)	$	10		$	18
Three Months Ended September 30, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	44
Purchased gas				(9		)
Electric fuel and other energy-related purchases				(4		)
Total commodity	$	(128	)	$	31		$	7
Interest rate(3)	(15		)	1			(4		)
Total	$	(143	)	$	32		$	3
Nine Months Ended September 30, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	(31	)
Purchased gas				(39		)
Electric fuel and other energy-related purchases				(6		)
Total commodity	$	(137	)	$	(76	)	$	3
Interest rate(3)	71			(12		)	66
Total	$	(66	)	$	(88	)	$	69
Nine Months Ended September 30, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	171
Purchased gas				(55		)
Electric fuel and other energy-related purchases				(16		)
Total commodity	$	159		$	100		$	14
Interest rate(3)	(91		)	2			(44		)
Total	$	68		$	102		$	(30	)
-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 September 30,						Nine Months Ended September 30,
Derivatives not designated as hedging instruments	2013			2012			2013			2012
(millions)
Derivative Type and Location of Gains (Losses)
Commodity
Operating revenue	$	3		$	5		$	—		$	108
Purchased gas	(3		)	3			(11		)	(2		)
Electric fuel and other energy-related purchases	(12		)	3			(20		)	(33		)
Interest rate(2)	—			10			—			17
Total	$	(12	)	$	21		$	(31	)	$	90
-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 tables below present Virginia Power's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
	30-Sep-13									31-Dec-12
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
(millions)
Interest rate contracts:
Over-the-counter	$	33		$	—		$	33		$	—		$	—	$	—
Commodity contracts:
Over-the-counter	2			—			2			6			—		6
Total derivatives, subject to a master netting or similar arrangement	35			—			35			6			—		6
Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—			—		—
Total(1)	$	35		$	—		$	35		$	6		$	—	$	6
-1	At September 30, 2013, the total derivative asset balance contains $35 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $6 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet.
				30-Sep-13											31-Dec-12
				Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts			Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
(millions)
Interest rate contracts:
Over-the-counter	$	33		$	—		$	—		$	33		$	—	$	—	$	—	$	—
Commodity contracts:
Over-the-counter	2			2			—			—			6		3		—		3
Total	$	35		$	2		$	—		$	33		$	6	$	3	$	—	$	3
	30-Sep-13									31-Dec-12
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Interest rate contracts:
Over-the-counter	$	—		$	—		$	—		$	25		$	—	$	25
Commodity contracts:
Over-the-counter	19			—			19			7			—		7
Exchange	1			—			1			2			—		2
Total derivatives, subject to a master netting or similar arrangement	20			—			20			34			—		34
Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—			—		—
Total(1)	$	20		$	—		$	20		$	34		$	—	$	34
-1	At September 30, 2013, the total derivative liability balance contains $20 million of current liabilities, which is presented in other current liabilities in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $33 million of current liabilities, which is presented in other current liabilities in Virginia Power’s Consolidated Balance Sheet and $1 million of noncurrent derivative liabilities, which is presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheet.
				30-Sep-13											31-Dec-12
				Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Paid			Net Amounts			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
(millions)
Interest rate contracts:
Over-the-counter	$	—		$	—		$	—		$	—		$	25	$	—	$	—	$	25
Commodity contracts:
Over-the-counter	19			2			14			3			7		3		—		4
Exchange	1			—			1			—			2		—		2		—
Total	$	20		$	2		$	15		$	3		$	34	$	3	$	2	$	29
The following table presents the volume of Virginia Power’s derivative activity as of September 30, 2013. 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	9			—
Basis	5			—
Electricity (MWh):
Fixed price	511,200			—
FTRs	63,408,139			—
Capacity (MW)	121,500			18,300
Interest rate	$	600,000,000		$	—
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 –			Fair Value –			Total Fair Value
	Derivatives under			Derivatives not under
	Hedge			Hedge
	Accounting			Accounting
(millions)
30-Sep-13
ASSETS
Current Assets
Commodity	$	1		$	1		$	2
Interest rate	33			—			33
Total current derivative assets(1)	34			1			35
Total derivative assets	$	34		$	1		$	35
LIABILITIES
Current Liabilities
Commodity	$	3		$	17		$	20
Total current derivative liabilities(2)	3			17			20
Total derivative liabilities	$	3		$	17		$	20
31-Dec-12
ASSETS
Current Assets
Commodity	$	1		$	5		$	6
Total current derivative assets(1)	1			5			6
Total derivative assets	$	1		$	5		$	6
LIABILITIES
Current Liabilities
Commodity	$	5		$	3		$	8
Interest rate	25			—			25
Total current derivative liabilities(2)	30			3			33
Noncurrent Liabilities
Commodity	1			—			1
Total noncurrent derivative liabilities(3)	1			—			1
Total derivative liabilities	$	31		$	3		$	34
-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			Amount of Gain			Increase
	(Loss)			(Loss) Reclassified			(Decrease) in
	Recognized			from AOCI to			Derivatives
	in AOCI  on			Income			Subject to
	Derivatives						Regulatory
	(Effective						Treatment(2)
	Portion)(1)
(millions)
Three Months Ended September 30, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(1	)
Total commodity	$	1		$	(1	)	$	4
Interest rate(3)	1			—			14
Total	$	2		$	(1	)	$	18
Three Months Ended September 30, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(1	)
Total commodity	$	—		$	(1	)	$	7
Interest rate(3)	(3		)	—			(4		)
Total	$	(3	)	$	(1	)	$	3
Nine Months Ended September 30, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	—
Total commodity	$	—		$	—		$	3
Interest rate(3)	7			—			66
Total	$	7		$	—		$	69
Nine Months Ended September 30, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(4	)
Total commodity	$	(1	)	$	(4	)	$	14
Interest rate(3)	(7		)	—			(44		)
Total	$	(8	)	$	(4	)	$	(30	)
-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 recorded in Virginia Power’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 September 30,						Nine Months Ended September 30,
Derivatives not designated as hedging instruments	2013			2012			2013			2012
(millions)
Derivative Type and Location of Gains (Losses)
Commodity(2)	$	(4	)	$	3		$	(8	)	$	(43	)
Interest rate(3)	—			1			—			—
Total	$	(4	)	$	4		$	(8	)	$	(43	)
-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 recorded in Virginia Power's Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.
-3	Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges.

Investments

Investments	9 Months Ended
	Sep. 30, 2013
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 $100 million and $95 million at September 30, 2013 and December 31, 2012, respectively. Cost method investments held in Dominion’s rabbi trusts totaled $10 million and $14 million at September 30, 2013 and December 31, 2012, 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		Total  Unrealized Gains(1)		Total  Unrealized				Fair Value
		Cost				Losses (1)
	(millions)
	30-Sep-13
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,176	$	999	$	—			$	2,175
	Other	48		20		—				68
	Marketable debt securities:
	Corporate bonds	339		17		(4		)		352
	U.S. Treasury securities and agency debentures	571		10		(7		)		574
	State and municipal	299		13		(4		)		308
	Other	4		—		—				4
	Cost method investments	103		—		—				103
	Cash equivalents and other(2)	89		—		—				89
	Total	$	2,629	$	1,059	$	(15	)	(3)	$	3,673
	December 31, 2012
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,210	$	732	$	—			$	1,942
	Other	40		13		—				53
	Marketable debt securities:
	Corporate bonds	295		30		—				325
	U.S. Treasury securities and agency debentures	523		19		(2		)		540
	State and municipal	248		26		—				274
	Other	6		1		—				7
	Cost method investments	117		—		—				117
	Cash equivalents and other(2)	72		—		—				72
	Total	$	2,511	$	821	$	(2	)	(3)	$	3,330
	-1	Included in AOCI and the decommissioning trust regulatory liability.
	-2	Includes pending sales of securities of $6 million and pending purchases of securities of $6 million at September 30, 2013 and December 31, 2012, respectively.
	-3	The fair value of securities in an unrealized loss position was $487 million and $195 million at September 30, 2013 and December 31, 2012, respectively.
	The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at September 30, 2013 by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	138
	Due after one year through five years	341
	Due after five years through ten years	358
	Due after ten years	401
	Total	$	1,238
	Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013			2012
	(millions)
	Proceeds from sales	$	398	$	276	$	1,260		$	1,040
	Realized gains(1)	29		15		121			71
	Realized losses(1)	13		6		29			25
	-1	Includes realized gains and 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 and nine months ended September 30, 2013 and 2012.
	Blue Racer
	In December 2012, Dominion formed Blue Racer with Caiman to provide midstream services to natural gas producers operating in the Utica Shale region in Ohio and portions of Pennsylvania. Blue Racer is an equal partnership between Dominion and Caiman, with Dominion contributing midstream assets and Caiman contributing private equity capital. In March 2013, DTI sold Line TL-404 to Blue Racer and received approximately $47 million in cash proceeds resulting in an approximately $25 million ($14 million after-tax) gain. Phase 1 of the Natrium natural gas processing and fractionation facility was completed in the second quarter of 2013 and was contributed to Blue Racer in the third quarter of 2013, resulting in an increased equity method investment in Blue Racer of $473 million. Also in the third quarter of 2013, East Ohio sold Line TPL-2A and DTI sold Line TL-388 to Blue Racer and received approximately $83 million in cash proceeds resulting in an approximately $75 million ($42 million after-tax) gain.
	Virginia Power
	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		Total  Unrealized		Total  Unrealized				Fair Value
		Cost		Gains(1)		Losses(1)
	(millions)
30-Sep-13
Marketable equity securities:
U.S.:
Large Cap	$	505	$	433	$	—			$	938
Other	23		10		—				33
Marketable debt securities:
Corporate bonds	191		9		(3		)		197
U.S. Treasury securities and agency debentures	209		2		(2		)		209
State and municipal	157		6		(3		)		160
Cost method investments	103		—		—				103
Cash equivalents and other(2)	28		—		—				28
Total	$	1,216	$	460	$	(8	)	(3)	$	1,668
December 31, 2012
Marketable equity securities:
U.S.:
Large Cap	$	481	$	298	$	—			$	779
Other	20		7		—				27
Marketable debt securities:
Corporate bonds	179		17		—				196
U.S. Treasury securities and agency debentures	231		4		(1		)		234
State and municipal	106		11		—				117
Other	1		—		—				1
Cost method investments	117		—		—				117
Cash equivalents and other(2)	44		—		—				44
Total	$	1,179	$	337	$	(1	)	(3)	$	1,515
-1	Included in AOCI and the decommissioning trust regulatory liability.
-2	Includes pending sales of securities of $4 million and $6 million at September 30, 2013 and December 31, 2012, respectively.
-3	The fair value of securities in an unrealized loss position was $247 million and $104 million at September 30, 2013 and December 31, 2012, respectively.
The fair value of Virginia Power’s marketable debt securities at September 30, 2013 by contractual maturity is as follows:
	Amount
(millions)
Due in one year or less	$	30
Due after one year through five years	158
Due after five years through ten years	199
Due after ten years	179
Total	$	566
Presented below is selected information regarding Virginia Power’s marketable equity and debt securities.
	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013			2012
(millions)
Proceeds from sales	$	140	$	128	$	464		$	481
Realized gains(1)	8		6		34			27
Realized losses(1)	5		2		13			9
-1	Includes realized gains and losses recorded to the decommissioning trust regulatory liability.
Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds for Virginia Power were not material for the three and nine months ended September 30, 2013 and 2012.

Regulatory_Assets_and_Liabilit

Regulatory Assets and Liabilities	9 Months Ended
	Sep. 30, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Regulatory Assets and Liabilities	'
	Regulatory Assets and Liabilities
	Regulatory assets and liabilities include the following:
		30-Sep-13		31-Dec-12
	(millions)
	Dominion
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	72	$	55
	Derivatives(2)	18		—
	Unrecovered gas cost(3)	21		59
	Plant retirement(4)	6		25
	Other	67		64
	Regulatory assets-current(5)	184		203
	Unrecognized pension and other postretirement benefit costs(6)	934		1,210
	Deferred rate adjustment clause costs(1)	257		173
	Income taxes recoverable through future rates(7)	164		140
	Derivatives(2)	34		105
	Other	89		89
	Regulatory assets-non-current	1,478		1,717
	Total regulatory assets	$	1,662	$	1,920
	Regulatory liabilities:
	PIPP(8)	$	143	$	100
	Other	45		36
	Regulatory liabilities-current(9)	188		136
	Provision for future cost of removal and AROs(10)	1,031		985
	Decommissioning trust(11)	617		501
	Other	70		28
	Regulatory liabilities-non-current	1,718		1,514
	Total regulatory liabilities	$	1,906	$	1,650
	Virginia Power
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	72	$	51
	Derivatives(2)	18		—
	Plant retirement(4)	6		25
	Other	50		43
	Regulatory assets-current(5)	146		119
	Deferred rate adjustment clause costs(1)	204		127
	Income taxes recoverable through future rates(7)	132		110
	Derivatives(2)	34		105
	Other	50		54
	Regulatory assets-non-current	420		396
	Total regulatory assets	$	566	$	515
	Regulatory liabilities:
	Other	$	37	$	32
	Regulatory liabilities-current(9)	37		32
	Provision for future cost of removal(10)	799		763
	Decommissioning trust(11)	617		501
	Other	55		21
	Regulatory liabilities-non-current	1,471		1,285
	Total regulatory liabilities	$	1,508	$	1,317
	-1	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 12 for more information.
	-2	For jurisdictions subject to cost-based rate regulation, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they are expected to be recovered from or refunded to customers.
	-3	Reflects unrecovered gas costs at Dominion's regulated gas operations, which are recovered through annual filings with the applicable regulatory authority.
	-4	Reflects costs anticipated to be recovered in base rates for certain coal units expected to be retired.
	-5	Current regulatory assets are presented in other current assets in Dominion's and Virginia Power's Consolidated Balance Sheets.
	-6	Represents unrecognized pension and other postretirement employee benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion's rate-regulated subsidiaries.
	-7	Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes.
	-8	Under PIPP, eligible customers can receive energy assistance based on their ability to pay. The difference between the customer's total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions.
	-9	Current regulatory liabilities are presented in other current liabilities in Dominion's and Virginia Power's Consolidated Balance Sheets.
	-10	Rates charged to customers by the Companies' regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.
	-11	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power's utility nuclear generation stations, in excess of the related AROs.
	At September 30, 2013, approximately $102 million of Dominion's and $65 million of Virginia Power's regulatory assets represented past expenditures on which they do not currently earn a return. These expenditures are expected to be recovered within the next two years.

Regulatory_Matters

Regulatory Matters	9 Months Ended
	Sep. 30, 2013
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. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may 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. 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. Virginia Power purchases and, under its FERC market-based rate authority, sells electricity in the wholesale market. 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 year each project enters commercial operation (but not before January 1, 2009). Virginia Power proposed an incentive of 1.5% for four of the projects (including the Meadow Brook-to-Loudoun and Carson-to-Suffolk lines, which were completed in 2011) and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008, the incentives were included in the PJM Tariff, and billing for the incentives was made accordingly. In 2012, PJM canceled one of the eleven projects with an estimated cost of $7 million. The total cost for the other ten projects included in Virginia Power's formula rate for 2013 is $852 million and the remaining projects were completed in 2012.  Numerous parties sought rehearing of the FERC order in August 2008. In May 2012, FERC issued an order denying the rehearing requests. In July 2012, the North Carolina Commission filed an appeal of the FERC orders with the U.S. Court of Appeals for the Fourth Circuit.  While Virginia Power cannot predict the outcome of the appeal, 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, did not oppose the settlement. The settlement was accepted by FERC in May 2012 and 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 allocation of the incremental cost of certain underground transmission facilities, which has been briefed pursuant to FERC's May 2012 order and awaits FERC action. While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations.
	Other Regulatory Matters
	Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 13 to the Consolidated Financial Statements in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2012 and Note 12 to the Consolidated Financial Statements in Dominion's and Virginia Power's Quarterly Reports on Form 10-Q for the quarters ended March 31, 2013 and June 30, 2013.
	Virginia Regulation
	Biennial Review
	Pursuant to the Regulation Act, in March 2013, Virginia Power submitted its base rate filings and accompanying schedules in support of the 2013 biennial review of its rates, terms and conditions, as well as of its earnings for test years 2011 and 2012. Virginia Power’s earnings test analysis, as filed, demonstrated it earned an ROE of 10.11% on its generation and distribution services for the combined test period of 2011 and 2012. In September 2013, the Virginia Commission conducted a hearing to receive evidence and public comments regarding Virginia Power’s base rate filings. During the hearing, Virginia Power updated its previous earnings test analysis to demonstrate that it earned an ROE of 10.30% on its generation and distribution services for the applicable test period. Although this ROE is more than 50 basis points below the authorized ROE of 10.9% established in its 2011 biennial review, Virginia Power did not request an increase in base rates for generation or distribution services in this proceeding. No parties to the proceeding asserted that Virginia Power earned above its authorized earnings band for a second consecutive biennial review, meaning that base rates are not statutorily subject to change in this proceeding. The Virginia Commission’s final order must be issued no later than November 28, 2013.
	In October 2013, Virginia Power filed a voluntary agreement with the Virginia Commission, proposing to issue a base rate credit of approximately $9 million from its 2012 revenues.  This voluntary base rate credit, if approved, would be effective April 1, 2014 and amortized for a twelve-month period.  This amount has no effect upon Virginia Power’s past or future earnings test results, and it does not constitute a credit or rate adjustment for purposes of the Regulation Act.  This credit is intended to offset and eliminate the revenue requirement increase for customers in certain rate adjustment clause cases resulting from the timing of a Virginia Power securities issuance.  A decision on this filing is pending.
	DSM Riders C1A and C2A
	In August 2013, Virginia Power filed an application with the Virginia Commission to continue Rider C1A and Rider C2A. Virginia Power proposed to continue cost recovery associated with DSM programs that were approved in its 2011 DSM case, as well as its previously approved electric vehicle pilot program. Virginia Power further requested approval to launch three new energy efficiency DSM programs that would be marketed as part of its existing non-residential bundle of DSM offerings. The requested revenue requirements are approximately $1 million for Rider C1A and approximately $35 million for Rider C2A. These amounts include operating expenses for Virginia Power’s proposed and previously approved programs above for the rate year beginning May 1, 2014 (including a gross-up or margin on expenses for energy efficiency programs), true-ups of the 2012 calendar year costs for the previously approved programs and carrying costs on the over-/under-recovery of costs. Virginia Power also proposed a combined spending cap of approximately $114 million, inclusive of lost revenues, for its three new DSM programs. This matter is pending.
	Virginia Fuel Expenses
	In October 2013, Virginia Power filed a voluntary request with the Virginia Commission to reduce its currently-approved fuel factor rate from 2.942 ¢/kWh to 2.572 ¢/kWh effective for usage on and after December 1, 2013, due to an anticipated over-recovery. This request is expected to reduce Virginia Power’s anticipated fuel recoveries through June 30, 2014 by more than $140 million. At September 30, 2013, Virgina Power's Consolidated Balance Sheet reflected $20 million of other current liabilities and $47 million of noncurrent regulatory liabilities related to fuel recoveries. Virginia Power has requested an order on this request by November 20, 2013.
	Bremo Power Station
	In September 2013, the Virginia Commission issued its final order approving an amended and reissued CPCN that would allow Virginia Power to convert Bremo Units 3 and 4 from coal to natural gas as their fuel source. The converted units must be in service by July 1, 2014, although this deadline can be extended for good cause. The proposed conversion will preserve 227 MW (net) of existing capacity and is expected to cost approximately $53 million, excluding financing costs.
	Brunswick County and Generation Rider BW
	In August 2013, three motions for reconsideration were filed with the Virginia Commission, asking that it reconsider its August 2013 final order approving a CPCN for construction of Brunswick County. In August 2013, the Virginia Commission granted the motions for the purpose of continuing its jurisdiction over these matters. Also in August 2013, two notices were filed to appeal the Virginia Commission's final order to the Supreme Court of Virginia. In September 2013, Virginia Power filed its notices of intent to participate in both appeals as an appellee. These matters are pending.
	The Virginia Commission previously approved Rider BW in conjunction with its approval of Brunswick County. In November 2013, Virginia Power requested Virginia Commission approval of its annual update for Rider BW for the twelve-month rate year beginning September 1, 2014, utilizing a 12.5% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE that Virginia Power has proposed, and which is pending a decision, in its 2013 biennial review case. Virginia Power proposed an approximately $101 million revenue requirement for the rate year. This case is pending.
	North Anna
	Virginia Power is considering the construction of a third nuclear unit at a site located at North Anna. In April 2013, Virginia Power decided to replace the reactor design previously selected for a potential unit with ESBWR technology.
	If Virginia Power decides to build a new unit, it must first receive a COL from the NRC, the approval of the Virginia Commission and certain environmental permits and other approvals. Virginia Power filed the first of its two-part amendment to the COL application with the NRC in July 2013 to reflect the ESBWR technology, and expects to file the second part of the amendment by the end of 2013. Virginia Power has not yet committed to building a new nuclear unit at North Anna.
	FERC - Gas
	Natrium-to-Market Project
	In September 2013, DTI received FERC authorization to construct the $42 million Natrium-to-Market project. The project is designed to provide 185,000 dekatherms per day of firm transportation from an interconnect between DTI and the Natrium facility to DTI’s interconnect with Texas Eastern Transmission, LP in Greene County Pennsylvania. Four customers have entered into binding precedent agreements for the full project capacity under 8-year and 13-year terms. The project is anticipated to be in service in November 2014.
	FERC - Other
	Pipeline G-150
	In May 2012, Dominion began construction of the $147 million pipeline G-150 project. The pipeline is designed to transport approximately 27,000 barrels per day of ethane from the Natrium facility to an interconnect with the ATEX line of Enterprise near Follansbee, West Virginia. Dominion NGL Pipelines, LLC, a subsidiary of Dominion, owns the 58-mile pipeline and associated equipment. Transportation services on the pipeline will be subject to FERC regulation pursuant to the Interstate Commerce Act. In August 2013, Dominion filed a petition for declaratory order requesting FERC approval, by mid-November 2013, of (1) general rate structure, (2) rate and terms for committed shipper, and (3) rate design for uncommitted shippers. The facilities are anticipated to be available in the first quarter of 2014 following commencement of operation of Enterprise's ATEX line and resumption of operations at the Natrium facility. Dominion NGL Pipelines, LLC is expected to be contributed to Blue Racer prior to commencement of service.

Variable_Interest_Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2013
Variable Interest Entities [Abstract]	'
Variable Interest Entities	'
	Variable Interest Entities
	As discussed in Note 15 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2012, 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 $920 million as of September 30, 2013. Virginia Power paid $53 million and $52 million for electric capacity and $29 million and $27 million for electric energy to these entities in the three months ended September 30, 2013 and 2012, respectively. Virginia Power paid $161 million and $160 million for electric capacity and $74 million and $62 million for electric energy to these entities in the nine months ended September 30, 2013 and 2012, respectively.
	Virginia Power purchased shared services from DRS, an affiliated VIE, of approximately $88 million and $86 million for the three months ended September 30, 2013 and 2012, respectively, and $248 million and $238 million for the nine months ended September 30, 2013 and 2012, 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.
	Dominion leased the Fairless generating facility in Pennsylvania from Juniper, the lessor, which began commercial operations in June 2004. Dominion made annual lease payments of approximately $53 million.
	Juniper was formed in 2003 as a limited partnership and was organized for the purpose of acquiring and constructing a number of assets for lease. Such assets were financed with proceeds from the issuance of bank debt, privately placed long-term debt and partnership capital received from Juniper's general and limited partners. Dominion had no voting equity interest in Juniper. Because Juniper had been subject to the business scope exception, Dominion was not required to evaluate whether Juniper was a VIE prior to October 2011.
	Through September 30, 2011, Juniper held various power plant leases, including Fairless. In October 2011, the last lease other than Fairless expired and the related asset was sold by Juniper. With Fairless being its sole remaining asset, Juniper no longer qualified as a business as of October 2011, which required that Dominion determine whether Juniper was a VIE. Dominion concluded Juniper was a VIE because the entity's capitalization was insufficient to support its operations, the power to direct the most significant activities of the entity was not held by the equity holders, and Dominion guaranteed a portion of the residual value of Fairless. The activities that most significantly impacted Juniper's economic performance related to the operation of Fairless. The decisions related to the operations of Fairless were made by Dominion and as such, Dominion was considered the primary beneficiary.
	Accordingly, Dominion consolidated Juniper in October 2011 and recorded, at fair value, approximately $957 million of property, plant and equipment, $896 million of debt and $61 million of noncontrolling interests. The debt was non-recourse to Dominion and was secured by Juniper's assets. The annual lease payments made by Dominion to Juniper for Fairless were eliminated in the Consolidated Statements of Income and were excluded from the lease commitments table in Note 22 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2012. Dominion did not provide any financial or other support to Juniper that it was not previously contractually required to provide.
	In August 2013, the lease expired and Dominion purchased Fairless for $923 million from Juniper per the terms of the lease agreement. However, as Dominion had previously consolidated Juniper, the purchase was accounted for as an equity transaction to acquire the noncontrolling interests from Juniper for $923 million, while Dominion retained control of Fairless. The acquisition resulted in the removal of securities due within one year-VIE and noncontrolling interests from Dominion's Consolidated Balance Sheet as of September 30, 2013.

Significant_Financing_Transact

Significant Financing Transactions	9 Months Ended
	Sep. 30, 2013
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 September 30, 2013, Dominion’s commercial paper and letters of credit outstanding, as well as its capacity available under credit facilities, were as follows:
		Facility			Outstanding			Outstanding			Facility
		Limit			Commercial			Letters of			Capacity
					Paper			Credit			Available
	(millions)
	Joint revolving credit facility(1)	$	3,000		$	2,145		$	—		$	855
	Joint revolving credit facility(2)	500			—			18			482
	Total	$	3,500		$	2,145		$	18		$	1,337
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018.  This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion of letters of credit.
	-2	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018.  Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018.  This credit facility 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 September 30, 2013, 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			Outstanding			Outstanding			Facility
		Sub-limit			Commercial			Letters of			Sub-limit Capacity
					Paper			Credit			Available
	(millions)
	Joint revolving credit facility(1)	$	1,000		$	485		$	—		$	515
	Joint revolving credit facility(2)	250			—			1			249
	Total	$	1,250		$	485		$	1		$	764
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018.  This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (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	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018.  Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018.  This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power's current sub-limit under this credit facility 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. Effective September 2013, the maturity date was extended from September 2017 to September 2018. As of September 30, 2013, this facility supports approximately $119 million of certain variable rate tax-exempt financings of Virginia Power.
	Long-term Debt
	In January 2013, Virginia Power issued $250 million of 1.2% senior notes and $500 million of 4.0% senior notes that mature in 2018 and 2043, respectively.
	In March 2013, Virginia Power issued $500 million of 2.75% senior notes that mature in 2023.
	In March 2013, Virginia Power redeemed the $50 million 2.5% IDA of the Town of Louisa, Virginia Solid Waste and Sewage Disposal Revenue Bonds, Series 2001A, that would have otherwise matured in March 2031. Virginia Power intends to redeem the $10 million 2.5% and the $30 million 2.5% IDA of the Town of Louisa, Virginia Solid Waste and Sewage Disposal Revenue Bonds, Series 1997A and 2000A, that would otherwise mature in April 2022 and September 2030, respectively. The bonds are expected to be redeemed on or before April 1, 2014 at the amount of principal then outstanding plus accrued interest. At September 30, 2013, the bonds were included in securities due within one year in Virginia Power's Consolidated Balance Sheets.
	In connection with the sale of Kincaid, in May 2013 Kincaid redeemed its 7.33% senior secured bonds due June 2020 with an outstanding principal amount of $145 million. The bonds were redeemed for approximately $185 million, including a make-whole premium and accrued interest.
	In connection with the sale of Brayton Point, Brayton Point provided notice of defeasance for three series of MDFA tax-exempt bonds, totaling approximately $257 million in outstanding principal amount, that would have otherwise matured in 2036 through 2042.  In June 2013, Brayton Point delivered approximately $284 million to fund an irrevocable trust for the purpose of paying maturing principal and interest due through and including the earliest redemption dates of the bonds in 2016 and 2019.  The bonds are no longer included in Dominion's Consolidated Balance Sheet.
	In June 2013, Brayton Point obtained bondholder consent and entered into a supplement to the Loan and Trust Agreement for approximately $75 million of variable rate MDFA Solid Waste Disposal Revenue Bonds, Series 2010B due 2041.  The supplement and associated assignment agreement changed the sole obligor under the bonds from Brayton Point to Dominion; the bonds continue to be included in Dominion's Consolidated Balance Sheet.
	In August 2013, Virginia Power issued $585 million of 4.65% senior notes that mature in 2043.
	Convertible Securities
	At September 30, 2013, Dominion had $44 million of outstanding contingent convertible senior notes that are convertible by holders into a combination of cash and shares of Dominion’s common stock under certain circumstances. The conversion feature requires that the principal amount of each note be repaid in cash, while amounts payable in excess of the principal amount will be paid in common stock. The conversion rate is subject to adjustment upon certain events such as subdivisions, splits, combinations of common stock or the issuance to all common stock holders of certain common stock rights, warrants or options and certain dividend increases. As of September 30, 2013, the conversion rate had been adjusted, primarily due to individual dividend payments above the level paid at issuance, to 29.7664 shares of common stock per $1,000 principal amount of senior notes, which represents a conversion price of $33.59. If the outstanding notes as of September 30, 2013 were all converted, it would result in the issuance of approximately 600,000 additional shares of common stock.
	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 nine months ended September 30, 2013, the senior notes were eligible for conversion and approximately $38 million of the notes were converted by holders. The senior notes are eligible for conversion during the fourth quarter of 2013.
	Junior Subordinated Notes Payable to Affiliated Trusts
	In January 2013, Dominion repaid its $258 million 7.83% unsecured junior subordinated debentures and redeemed all 250 thousand units of the $250 million 7.83% Dominion Resources Capital Trust I capital securities due December 1, 2027. The securities were redeemed at a price of $1,019.58 per capital security plus accrued and unpaid distributions.
	Remarketable Subordinated Notes
	In June 2013, Dominion issued $550 million of 2013 Series A 6.125% Equity Units and $550 million of 2013 Series B 6% Equity Units, initially in the form of Corporate Units. The Corporate Units are listed on the New York Stock Exchange under the symbols DCUA and DCUB, respectively.
	Each Corporate Unit consists of a stock purchase contract and 1/20 interest in a RSN issued by Dominion. The stock purchase contracts obligate the holders to purchase shares of Dominion common stock at a future settlement date prior to the relevant RSN maturity date. The purchase price to be paid under the stock purchase contracts is $50 and the number of shares to be purchased will be determined under a formula based upon the average closing price of Dominion common stock near the settlement date. The RSNs are pledged as collateral to secure the purchase of common stock under the related stock purchase contracts.
	Dominion makes quarterly interest payments on the RSNs and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. Dominion may defer payments on the stock purchase contracts and the RSNs for one or more consecutive periods but generally not beyond the purchase contract settlement date. If payments are deferred, Dominion may not make any cash distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments. Also, during the deferral period, Dominion may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the RSNs.
	Dominion has recorded the present value of the stock purchase contract payments as a liability offset by a charge to additional paid-in capital in equity. Interest payments on the RSNs are recorded as interest expense and stock purchase contract payments are charged against the liability. Accretion of the stock purchase contract liability is recorded as imputed interest expense. In calculating diluted EPS, Dominion applies the treasury stock method to the Equity Units. These securities did not have an effect on diluted EPS for the third quarter of 2013.
	Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, Dominion will issue between 8.4 million and 9.9 million shares of its common stock in both April 2016 and July 2016. A total of 22.5 million shares of Dominion's common stock has been reserved for issuance in connection with the stock purchase contracts.
	Selected information about Dominion's Equity Units is presented below:
	Issuance Date	Units Issued		Total Net Proceeds			Total Long-term Debt			RSN Annual Interest Rate		Stock Purchase Contract Annual Rate		Stock Purchase Contract Liability		Stock Purchase Settlement Date	RSN Maturity Date
	(millions, except interest rates)
	6/7/13	11		$	533.5		$	550		1.07	%	5.055	%	$	76.7	4/1/16	4/1/21
	6/7/13	11		$	533.5		$	550		1.18	%	4.82	%	$	79.3	7/1/16	7/1/19
	Regulated Natural Gas Financing Plans
	In September 2013, Dominion announced the formation of DGH, a first tier subsidiary holding company for the majority of Dominion’s regulated natural gas businesses. Specifically, Dominion transferred direct ownership of East Ohio, DTI and Dominion Iroquois, Inc., the latter of which holds a 24.72% general partnership interest in Iroquois Gas Transmission System, L.P., to DGH on September 30, 2013. Dominion intends to seek approval from the West Virginia Commission in 2014 for the transfer of direct ownership of Hope Gas, Inc. to DGH. DGH issued $1.2 billion principal amount of unsecured senior notes in a private placement on October 22, 2013 and will be the primary financing entity for Dominion’s regulated natural gas businesses. DGH expects to become an SEC registrant in 2014. DGH used the proceeds from the October 2013 offering to settle intercompany long-term notes from Dominion and to repay a portion of its intercompany revolving credit agreement balances with Dominion.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2013
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 such matters that the Companies cannot estimate, 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. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may 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, as amended, 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.
	The EPA established CAIR with the intent to require significant reductions in SO2 and NOX emissions from electric generating facilities. In July 2008, the U.S. Court of Appeals for the D.C. Circuit issued a ruling vacating CAIR. In December 2008, the Court denied rehearing, but also issued a decision to remand CAIR to the EPA. In July 2011, the EPA issued a replacement rule for CAIR, called CSAPR, that required 28 states to reduce power plant emissions that cross state lines. CSAPR established new SO2 and NOx emissions cap and trade programs that were completely independent of the current ARP. Specifically, CSAPR required reductions in SO2 and NOx emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NOx emissions caps, NOx 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.
	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. In February and June 2012, the EPA issued technical revisions to CSAPR that were not material to Dominion. In August 2012, the court vacated CSAPR in its entirety and ordered the EPA to implement CAIR until a valid replacement rule is issued. In October 2012, the EPA filed a petition requesting a rehearing of the court's decision, which was denied in January 2013. The mandate vacating CSAPR was issued in February 2013. In March 2013, the EPA and several environmental groups filed petitions with the U.S. Supreme Court requesting review of the decision to vacate and remand CSAPR. In June 2013, the U.S. Supreme Court granted the EPA's petition seeking review of the D.C. Circuit's decision that vacated and remanded CSAPR. With respect to Dominion's generation fleet, the cost to comply with CAIR is not expected to be material. Future outcomes of litigation and/or any additional action to issue a revised rule could affect the assessment regarding cost of compliance.
	In May 2012, the EPA issued final designations for the 75-ppb ozone air quality standard. Several Dominion electric generating facilities are located in areas impacted by this standard. As part of the standard, states will be required to develop and implement plans to address sources emitting pollutants which contribute to the formation of ozone. Until the states have developed implementation plans, Dominion is unable to predict whether or to what extent the new rules will ultimately require additional controls.
	In February 2008, Dominion received a request for information pursuant to Section 114 of the CAA from the EPA. The request concerned 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. In May 2010, Dominion received a request for information pursuant to Section 114 of the CAA from the EPA. The request concerned historical operating changes and capital improvements undertaken at Brayton Point.
	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. Dominion entered into settlement discussions with the U.S. government and reached an agreement to settle the allegations. In April 2013, the U.S. government lodged a consent decree and complaint with the U.S. District Court for the Central District of Illinois that resolves all alleged violations at State Line, Kincaid and Brayton Point. The settlement mandates the closure of State Line, installation of certain control technology at Kincaid and Brayton Point, the achievement of certain emissions limitations, payment of a civil penalty of $3 million and funding of $10 million in environmental mitigation projects. The consent decree underwent a 30-day public comment period and the U.S. government has filed a motion with the court requesting that the decree be entered as lodged. In July 2013, the court entered the consent decree, concluding the enforcement action. Dominion previously accrued a liability of $13 million related to this matter.  State Line ceased operations in March 2012 and was sold in June 2012.  The installation of pollution control technology was in progress at Kincaid and had been completed at Brayton Point. In August 2013, Dominion sold Kincaid and Brayton Point. Under the terms of the sale transaction, Dominion retained the $13 million liability associated with the settlement agreement. Dominion has paid the civil penalty and is implementing the environmental mitigation projects.
	Water
	The CWA, as amended, 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 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. The report summarizing the results of the evaluation was submitted in August 2012 and is under review by the Connecticut Department of Energy and Environmental Protection. Dominion cannot currently predict the outcome of this review. 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 jointly, severally and strictly 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, three of which pertain to Virginia Power. 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 former sites with which Dominion and Virginia Power are 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. Dominion is currently evaluating the nature and extent of the contamination from this site as well as potential remedial options, but is not yet able to estimate 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, Connecticut, and Maryland, 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 underwent a program review, and in February 2013, revisions to the RGGI model rule were issued that include a reduction of the regional CO2 emissions cap from 165 million tons to 91 million tons beginning in January 2014, with an additional 2.5% reduction per year through 2020. The revisions also include changes to compliance demonstration requirements for regulated entities, offset and cost containment mechanisms. The RGGI states are in the process of conducting the regulatory and/or legislative processes required to amend existing state regulations to implement the RGGI program changes. Dominion is in the process of evaluating these revisions as to potential impacts on Dominion's operations in RGGI states.  However, as a result of the recent sales of several power plants located in
	these states, Dominion does not expect that RGGI will have a material effect on operations, financial condition, and/or cash flows.
	Natrium and Blue Racer
	In January 2011, Dominion announced the development of a natural gas processing and fractionation facility in Natrium, West Virginia, and in July 2011 it executed a contract for the construction of the first phase of the facility. The first phase of the project is fully contracted and was placed into service in May 2013. In August 2013, the Natrium natural gas processing and fractionation facility was contributed to the Blue Racer joint venture. In September 2013, the Natrium facility was shut down following a fire at the plant. This matter is not anticipated to have a material impact on Dominion’s financial condition, results of operations, and/or cash flows.
	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 July 2011, an NRC task force provided initial recommendations based on its review of the Fukushima Daiichi accident and in October 2011 the NRC staff prioritized these recommendations into Tiers 1, 2 and 3, with the Tier 1 recommendations consisting of actions which the staff determined should be started without unnecessary delay. In December 2011, the NRC Commissioners approved the agency staff's prioritization and recommendations, and that same month an appropriations act directed the NRC to require reevaluation of external hazards (not limited to seismic and flooding hazards) as soon as possible.
	Based on the prioritized recommendations, 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. Implementation of these enhancements is currently in progress. The 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. Dominion and Virginia Power do not currently expect that compliance with the NRC's March 2012 orders and information requests will materially impact their financial position, results of operations or cash flows during the approximately four-year implementation period. The NRC staff is evaluating the implementation of the longer term Tier 2 and Tier 3 recommendations. Dominion and Virginia Power are currently unable to estimate the potential financial impacts related to compliance with Tier 2 and Tier 3 recommendations.
	Nuclear Operations
	Nuclear Insurance
	The Price-Anderson Amendments Act of 1988 provides the public up to $13.6 billion of liability protection per nuclear incident, via obligations required of owners of nuclear power plants, and allows for an inflationary provision adjustment every five years. Dominion and Virginia Power have purchased $375 million of coverage from commercial insurance pools for each reactor site with the remainder provided through a mandatory industry retrospective rating plan. In the event of a nuclear incident at any licensed nuclear reactor in the U.S., the Companies could be assessed up to $127 million for each of their licensed reactors not to exceed $19 million per year per reactor. There is no limit to the number of incidents for which this retrospective premium can be assessed.
	Effective June 7, 2013 for Kewaunee and July 1, 2013 for Millstone and Virginia Power's nuclear units, the levels of nuclear property insurance coverage were reduced to the following:
		Coverage
	(billions)
	Dominion
	Millstone	$	1.7
	Kewaunee	1.06
	Virginia Power(1)
	Surry	$	1.7
	North Anna	1.7
	-1	Surry and North Anna share a blanket property limit of $450 million.
	The Companies' nuclear property insurance coverage for Millstone, Surry and North Anna exceeds the NRC minimum requirement for nuclear power plant licensees of $1.06 billion per reactor site. Kewaunee meets the NRC minimum requirement of $1.06 billion. This includes coverage for premature decommissioning and functional total loss. The NRC requires that the proceeds from this insurance be used first, to return the reactor to and maintain it in a safe and stable condition and second, to decontaminate the reactor and station site in accordance with a plan approved by the NRC. Nuclear property insurance is provided by NEIL, a mutual insurance company, and is subject to retrospective premium assessments in any policy year in which losses exceed the funds available to the insurance company. Dominion's and Virginia Power's maximum retrospective premium assessment for the current policy period is $71 million and $39 million, respectively. Based on the severity of the incident, the board of directors of the nuclear insurer has the discretion to lower or eliminate the maximum retrospective premium assessment. Dominion and Virginia Power have the financial responsibility for any losses that exceed the limits or for which insurance proceeds are not available because they must first be used for stabilization and decontamination.
	Millstone and Virginia Power also purchase accidental outage insurance from NEIL to mitigate certain expenses, including replacement power costs, associated with the prolonged outage of a nuclear unit due to direct physical damage. Under this program, the Companies are subject to a retrospective premium assessment for any policy year in which losses exceed funds available to NEIL. Dominion's and Virginia Power's maximum retrospective premium assessment for the current policy period is $19 million and $9 million, respectively. Kewaunee's accidental outage policy for replacement power costs was canceled on February 1, 2013.
	ODEC, a part owner of North Anna, and Massachusetts Municipal Wholesale Electric Company and Green Mountain Power Corporation, part owners of Millstone's Unit 3, are responsible to Dominion and Virginia Power for their share of the nuclear decommissioning obligation and insurance premiums on applicable units, including any retrospective premium assessments and any losses not covered by insurance.
	Guarantees
	Dominion
	At September 30, 2013, Dominion had issued $68 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of September 30, 2013, Dominion’s exposure under these guarantees was $38 million, primarily related to certain reserve requirements associated with non-recourse financing.
	In addition to the above guarantees, Dominion and its partners, Shell and BP, may be required to make additional periodic equity contributions to NedPower and Fowler Ridge in connection with certain funding requirements associated with their respective non-recourse financings. As of September 30, 2013, Dominion's maximum remaining cumulative exposure under these equity funding agreements was $90 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million.
	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 the 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 September 30, 2013, Dominion had issued the following subsidiary guarantees:
		Stated Limit		Value(1)
	(millions)
	Subsidiary debt(2)	$	27	$	27
	Commodity transactions(3)	3,181		343
	Nuclear obligations(4)	232		55
	Cove Point(5)	335		—
	Other(6)	648		92
	Total	$	4,423	$	517
	-1	Represents the estimated portion of the guarantee's stated limit that is utilized as of September 30, 2013 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	Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, 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. The agreement for Kewaunee also provides for funds through the completion of decommissioning.
-5	Guarantees related to Cove Point, including agreements to support terminal service and transportation agreements as well as an engineering, procurement and construction contract for new liquefaction facilities. Includes certain guarantees that do not have stated limits.
-6	Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries' obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower.
Surety Bonds and Letters of Credit
As of September 30, 2013, Dominion had purchased $146 million of surety bonds, including $59 million at Virginia Power, and authorized the issuance of letters of credit by financial institutions of $18 million, including $1 million at Virginia Power, to facilitate commercial transactions by its subsidiaries with third parties. Under the terms of surety bonds, the Companies are obligated to indemnify the respective surety bond company for any amounts paid.

Credit_Risk

Credit Risk	9 Months Ended
	Sep. 30, 2013
Risks and Uncertainties [Abstract]	'
Credit Risk	'
	Credit Risk
	Dominion’s and Virginia Power’s accounting policies for credit risk are discussed in Note 23 to the Consolidated Financial Statements in their Annual Report on Form 10-K for the year ended December 31, 2012.
	At September 30, 2013, Dominion's credit exposure totaled $205 million. Of this amount, investment grade counterparties, including those internally rated, represented 63%. No counterparty exposure exceeded 10% of Dominion's total exposure.
	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 September 30, 2013 and December 31, 2012, Dominion would have been required to post an additional $48 million and $110 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 approximately $3 million and $4 million in collateral at September 30, 2013 and December 31, 2012, respectively, related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. The collateral posted includes any amounts paid related to non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. The aggregate fair value of all derivative instruments with credit-related contingent provisions that are in a liability position and not fully collateralized with cash as of September 30, 2013 and December 31, 2012 was $86 million and $163 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 September 30, 2013 and December 31, 2012. See Note 9 for further information about derivative instruments.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
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. As of September 30, 2013 and December 31, 2012, Virginia Power's derivative liabilities with affiliates were not material.
	DRS and other 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 September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
	(millions)
	Commodity purchases from affiliates	$	138	$	129	$	328	$	285
	Services provided by affiliates	109		107		311		298
	Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. There were $243 million in short-term demand note borrowings from Dominion as of December 31, 2012. There were no short-term demand note borrowings from Dominion as of September 30, 2013. Virginia Power's outstanding borrowings, net of repayments, under the Dominion money pool for its nonregulated subsidiaries totaled $192 million as of December 31, 2012. There were no borrowings as of September 30, 2013. Interest charges related to Virginia Power's borrowings from Dominion were not material for the three and nine months ended September 30, 2013 and 2012.

Employee_Benefit_Plans

Employee Benefit Plans	9 Months Ended
	Sep. 30, 2013
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
		2013			2012			2013			2012
	(millions)
	Three Months Ended September 30,
	Service cost	$	31		$	29		$	10		$	11
	Interest cost	69			67			19			20
	Expected return on plan assets	(116		)	(108		)	(24		)	(19		)
	Amortization of prior service credit	—			—			(3		)	(4		)
	Amortization of net loss	37			33			2			2
	Settlements and curtailments(1)	—			—			—			(4		)
	Net periodic benefit cost	$	21		$	21		$	4		$	6
	Nine Months Ended September 30,
	Service cost	$	100		$	87		$	34		$	33
	Interest cost	202			201			56			60
	Expected return on plan assets	(345		)	(323		)	(68		)	(60		)
	Amortization of prior service cost (credit)	2			2			(9		)	(10		)
	Amortization of net loss	127			99			6			5
	Settlements and curtailments(1)(2)	(2		)	—			(15		)	(4		)
	Net periodic benefit cost	$	84		$	66		$	4		$	24
	(1) 2012 amount relates primarily to the sale of Salem Harbor.
	(2) 2013 amount relates primarily to the decommissioning of Kewaunee.
	Pension and Other Postretirement Plan Remeasurement
	Dominion remeasured all of its pension and other postretirement benefit plans in the second quarter of 2013. The remeasurement resulted in a reduction in the pension benefit obligation of approximately $354 million and a reduction in the accumulated postretirement benefit obligation of approximately $78 million. The impact of the remeasurement on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date. The remeasurement is expected to reduce net periodic benefit cost for 2013 by approximately $36 million, excluding the impacts of curtailments. The discount rate used for the remeasurement was 4.8% for the pension plans and 4.7% for the other postretirement benefit plans. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2012.
	Employer Contributions
	During the nine months ended September 30, 2013, Dominion made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion expects to contribute approximately $12 million to its other postretirement benefit plans through Voluntary Employees' Beneficiary Associations during the remainder of 2013.

Goodwill

Goodwill	9 Months Ended
	Sep. 30, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill	'
	Goodwill
	The changes in Dominion's carrying amount and segment allocation of goodwill are presented below:
		Dominion					Dominion					DVP					Corporate and		Total
		Generation					Energy										Other
	(millions)
	Balance at December 31, 2011(1)	$	1,338				$	712				$	1,091				$	—	$	3,141
	Asset disposition adjustment	—					(11		)			—					—		(11		)
	Balance at December 31, 2012(1)	$	1,338				$	701				$	1,091				$	—	$	3,130
	Asset disposition adjustment	(16		)	(2	)	(24		)	(3	)	(3		)	(2	)	—		(43		)
	Balance at September 30, 2013(1)	$	1,322				$	677				$	1,088				$	—	$	3,087
	-1	Goodwill amounts do not contain any accumulated impairment losses.
	-2	See Note 3 in this report for a discussion of Dominion's dispositions and related goodwill write-offs.
	-3	Related to assets sold or contributed to Blue Racer.

Operating_Segments

Operating Segments	9 Months Ended
	Sep. 30, 2013
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 the net impact of operations that are expected to be or are currently discontinued. In addition, Corporate and Other includes specific items attributable to Dominion's operating segments that are not included in profit measures evaluated by executive management in assessing the segments' performance or allocating resources among the segments.
	In the second quarter of 2013, Dominion commenced a restructuring of its producer services business, which aggregates natural gas supply, engages in natural gas trading and marketing activities and natural gas supply management and provides price risk management services to Dominion affiliates. The restructuring will result in the termination of natural gas trading and certain energy marketing activities. As a result, the earnings impact from natural gas trading and certain energy marketing activities has been included in the Corporate and Other Segment of Dominion.
	In the nine months ended September 30, 2013, Dominion reported after-tax net expense of $148 million for specific items in the Corporate and Other segment, with $144 million of these net expenses attributable to its operating segments. In the nine months ended September 30, 2012, Dominion reported after-tax net expense of $413 million for specific items in the Corporate and Other segment, with $422 million of these net expenses attributable to its operating segments.
	The net expense for specific items in 2013 primarily related to the impact of the following items:
	•	A $135 million ($92 million after-tax) net loss from discontinued operations of Brayton Point and Kincaid, including debt extinguishment of $64 million ($38 million after-tax) related to the sale, impairment charges of $48 million ($28 million after-tax), a $17 million ($18 million after-tax) loss on the sale which includes a $16 million write-off of goodwill, and a $6 million ($8 million after-tax) loss from operations, attributable to Dominion Generation;
	•	A $130 million ($74 million after-tax) net loss, including a $55 million ($33 million after-tax) impairment charge related to certain natural gas infrastructure assets and a $75 million ($41 million after-tax) loss related to the producer services business discussed above, attributable to Dominion Energy; and
	•	A $28 million ($17 million after-tax) charge primarily reflecting severance pay and other benefits related to workforce reductions, attributable to all segments; partially offset by
	•	A $66 million ($40 million after-tax) net gain on investments held in nuclear decommissioning trust funds, attributable to Dominion Generation; and
	•	A $35 million ($25 million after-tax) gain related to the sale of Dominion's equity method investment in Elwood, attributable to Dominion Generation.
	The net expense for specific items in 2012 primarily related to the impact of the following items:
	•	A $458 million ($297 million after-tax) net loss, including impairment charges, primarily resulting from management's decision to cease operations and begin decommissioning Kewaunee in 2013, attributable to Dominion Generation;
	•	A $98 million ($72 million after-tax) net loss from discontinued operations of Brayton Point and Kincaid, attributable to Dominion Generation, including $25 million of additional tax expense for the potential loss or recapture of state tax credits. Dominion announced its intention to pursue the sale of these two merchant power stations in the third quarter of 2012;
	•	A $69 million ($42 million after-tax) charge reflecting restoration costs associated with damage caused by late June 2012 summer storms, attributable to DVP; and
	•	A $49 million ($22 million after-tax) loss from discontinued operations of State Line and Salem Harbor which were sold in 2012, attributable to Dominion Generation.
	The Corporate and Other Segment of Virginia Power primarily includes specific items attributable to its operating segments that are not included in profit measures evaluated by executive management in assessing the segments' performance or allocating resources among the segments.
	In the nine months ended September 30, 2013 and 2012, Virginia Power reported after-tax net expense of $5 million and $41 million, respectively, for specific items in the Corporate and Other segment, all of which was attributable to its operating segments.
	The net expense for specific items in 2012 primarily related to the impact of a $69 million ($42 million after-tax) charge reflecting restoration costs associated with damage caused by late June 2012 summer storms, attributable to DVP.
	The following table presents segment information pertaining to Dominion’s operations:
		DVP			Dominion		Dominion			Corporate			Adjustments/Eliminations			Consolidated
					Generation(1)		Energy			and Other(1)						Total
	(millions)
	Three Months Ended September 30,
	2013
	Total revenue from external customers	$	829		$	1,882	$	361		$	(10	)	$	370		$	3,432
	Intersegment revenue	8			110		281			158			(557		)	—
	Total operating revenue	837			1,992		642			148			(187		)	3,432
	Loss from discontinued operations	—			—		—			(23		)	—			(23		)
	Net income (loss) attributable to Dominion	124			338		169			(62		)	—			569
	2012
	Total revenue from external customers	$	836		$	1,824	$	291		$	37		$	344		$	3,332
	Intersegment revenue	6			110		281			164			(561		)	—
	Total operating revenue	842			1,934		572			201			(217		)	3,332
	Loss from discontinued operations	—			—		—			(52		)	—			(52		)
	Net income (loss) attributable to Dominion	119			363		104			(377		)	—			209
	Nine Months Ended September 30,
	2013
	Total revenue from external customers	$	2,508		$	5,034	$	1,326		$	54		$	1,013		$	9,935
	Intersegment revenue	56			237		821			464			(1,578		)	—
	Total operating revenue	2,564			5,271		2,147			518			(565		)	9,935
	Loss from discontinued operations	—			—		—			(92		)	—			(92		)
	Net income (loss) attributable to Dominion	398			730		472			(334		)	—			1,266
	2012
	Total revenue from external customers	$	2,573		$	4,960	$	1,278		$	109		$	814		$	9,734
	Intersegment revenue	81			275		701			459			(1,516		)	—
	Total operating revenue	2,654			5,235		1,979			568			(702		)	9,734
	Loss from discontinued operations	—			—		—			(94		)	—			(94		)
	Net income (loss) attributable to Dominion	428			762		362			(591		)	—			961
	-1	2012 amounts have been recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
	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		Corporate			Consolidated
				Generation		and Other			Total
(millions)
Three Months Ended September 30,
2013
Operating revenue	$	470		$	1,589	$	—		$	2,059
Net income	123			262		2			387
2012
Operating revenue	$	505		$	1,581	$	—		$	2,086
Net income	128			283		4			415
Nine Months Ended September 30,
2013
Operating revenue	$	1,366		$	4,184	$	—		$	5,550
Net income (loss)	355			587		(3		)	939
2012
Operating revenue	$	1,413		$	4,183	$	—		$	5,596
Net income (loss)	335			534		(39		)	830

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2013
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 September 30, 2013, their results of operations for the three and nine months ended September 30, 2013 and 2012 and their cash flows for the nine months ended September 30, 2013 and 2012. 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 2012 Consolidated Financial Statements and Notes have been reclassified to conform to the 2013 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.

Dispositions_Tables

Dispositions (Tables)	9 Months Ended
	Sep. 30, 2013
Brayton Point and Kincaid	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures	'
	The following table presents selected information regarding the results of operations of Brayton Point and Kincaid, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013				2012
	(millions)
	Operating revenue	$	87		$	77		$	304			$	191
	Loss before income taxes	(17		)	(50		)	(135		)	(1)	(98		)
	-1	Includes $64 million of charges related to the early redemption of Brayton Point and Kincaid debt. See Note 14 in this report for more information.
State Line and Salem Harbor	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures	'
	The following table presents selected information regarding the results of operations of Salem Harbor and State Line, which are classified in discontinued operations in Dominion's Consolidated Statements of Income:
		Three Months Ended September 30, 2012			Nine Months Ended September 30, 2012
	(millions)
	Operating revenue	$	5		$	57
	Loss before income taxes	(19		)	(49		)

Operating_Revenue_Tables

Operating Revenue (Tables)	9 Months Ended
	Sep. 30, 2013
Regulated and Unregulated Operating Revenue [Abstract]	'
Operating Revenue	'
	The Companies’ operating revenue consists of the following:
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
	(millions)
	Dominion
	Electric sales:
	Regulated	$	2,023	$	2,046	$	5,471	$	5,495
	Nonregulated	704		661		1,907		1,930
	Gas sales:
	Regulated	32		34		213		166
	Nonregulated	159		177		712		740
	Gas transportation and storage	329		297		1,156		1,007
	Other	185		117		476		396
	Total operating revenue	$	3,432	$	3,332	$	9,935	$	9,734
	Virginia Power
	Regulated electric sales	$	2,023	$	2,046	$	5,471	$	5,495
	Other	36		40		79		101
	Total operating revenue	$	2,059	$	2,086	$	5,550	$	5,596

Income_Taxes_Tables

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2013
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
	Nine Months Ended September 30,	2013		2012		2013		2012
	U.S. statutory rate	35	%	35	%	35	%	35	%
	Increases (reductions) resulting from:
	State taxes, net of federal benefit	2.4		4.4		2.8		3.9
	Investment and production tax credits	(1.8	)	(0.6	)	(0.2	)	—
	Valuation allowances	—		(0.9	)	—		—
	AFUDC - equity	(0.7	)	(0.9	)	(1.1	)	(0.8	)
	Other, net	(0.9	)	(2.1	)	(0.3	)	0.1
	Effective tax rate	34	%	34.9	%	36.2	%	38.2	%
Schedule of Unrecognized Tax Benefits Roll Forward	'
	During the nine months ended September 30, 2013, Dominion's and Virginia Power's unrecognized tax benefits changed as follows:
		Dominion		Virginia Power
	(millions)
	Balance at January 1, 2013	$293		$57
	Increases - prior period positions	14		12
	Decreases - prior period positions	(91	)	(42	)
	Current period positions	21		7
	Settlements	(2	)	(2	)
	Expiration of statutes of limitations	(4	)	—
	Balance at September 30, 2013	$231		$32

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share Computation	'
	The following table presents the calculation of Dominion’s basic and diluted EPS:
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
	(millions, except EPS)
	Net income attributable to Dominion	$	569	$	209	$	1,266	$	961
	Average shares of common stock outstanding – Basic	579.4		573.8		578.1		572.1
	Net effect of dilutive securities(1)	0.7		0.9		0.7		1.1
	Average shares of common stock outstanding – Diluted	580.1		574.7		578.8		573.2
	Earnings Per Common Share – Basic	$	0.98	$	0.36	$	2.19	$	1.68
	Earnings Per Common Share – Diluted	$	0.98	$	0.36	$	2.19	$	1.68
	-1	Dilutive securities consist primarily of contingently convertible senior notes. See Note 14 in this report for more information.

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Tables)	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	The following table presents Dominion’s changes in AOCI by component, net of tax:
		Deferred gains and losses on derivatives-hedging activities			Unrealized gains and losses on investment securities			Unrecognized pension and other postretirement benefit costs			Total
	(millions)
	Three Months Ended September 30, 2013
	Beginning balance	$	(31	)	$	371		$	(823	)	$	(483	)
	Other comprehensive income before reclassifications: gains (losses)	(77		)	38			(12		)	(51		)
	Amounts reclassified from accumulated other comprehensive income(1): (gains) losses	(6		)	(10		)	14			(2		)
	Net current-period other comprehensive income (loss)	(83		)	28			2			(53		)
	Ending balance	$	(114	)	$	399		$	(821	)	$	(536	)
	Nine Months Ended September 30, 2013
	Beginning balance	$	(122	)	$	326		$	(1,081	)	$	(877	)
	Other comprehensive income before reclassifications: gains (losses)	(45		)	119			216			290
	Amounts reclassified from accumulated other comprehensive income(1): (gains) losses	53			(46		)	44			51
	Net current-period other comprehensive income (loss)	8			73			260			341
	Ending balance	$	(114	)	$	399		$	(821	)	$	(536	)
	(1) See table below for details about these reclassifications.
Reclassification out of Accumulated Other Comprehensive Income	'
	The following table presents Dominion’s reclassifications out of AOCI by component:
	Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
	(millions)
	Three Months Ended September 30, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	(24	)	Operating revenue
		5			Purchased gas
		3			Electric fuel and other energy-related purchases
	Interest rate contracts	6			Interest and related charges
		(10		)
	Tax	4			Income tax expense
		$	(6	)
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(16	)	Other income
	Impairment	1			Other income
		(15		)
	Tax	5			Income tax expense
		$	(10	)
	Unrecognized pension and other postretirement benefit costs:
	Actuarial losses	$	23		Other operations and maintenance
		23
	Tax	(9		)	Income tax expense
		$	14
	Nine Months Ended September 30, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	31		Operating revenue
		39			Purchased gas
		6			Electric fuel and other energy-related purchases
	Interest rate contracts	12			Interest and related charges
		88
	Tax	(35		)	Income tax expense
		$	53
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(80	)	Other income
	Impairment	6			Other income
		(74		)
	Tax	28			Income tax expense
		$	(46	)
	Unrecognized pension and other postretirement benefit costs:
	Prior service costs	$	(6	)	Other operations and maintenance
	Actuarial losses	79			Other operations and maintenance
		73
	Tax	(29		)	Income tax expense
		$	44

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'
Fair Value, Option, Quantitative Disclosures	'
	The following table presents Dominion's and Virginia Power's quantitative information about Level 3 fair value measurements. The range and weighted average are presented in dollars for market price inputs, years for mean reversion speeds, and percentages for price volatility, price correlations, load shaping, and usage factors.
		Fair Value (millions)			Valuation Techniques	Unobservable Input		Range	Weighted Average(1)
	At September 30, 2013
	Assets:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	10		Discounted Cash Flow	Market Price (per Dth)	(4)	(1) - 5	2
	Electricity	9			Discounted Cash Flow	Market Price (per MWh)	(4)	31 - 77	44
	FTRs(3)	1			Discounted Cash Flow	Market Price (per MWh)	(4)	(1) - 6	0
	Liquids	12			Discounted Cash Flow	Market Price (per Gal)	(4)	0 - 3	1
	Physical and Financial Options:
	Natural Gas	7			Option Model	Market Price (per Dth)	(4)	5-Mar	4
						Price Volatility	(5)	19% - 30%	24	%
						Price Correlation	(6)	(9)% - 100%	36	%
						Mean Reversion	(7)	0 - 58	4
	Full Requirements Contracts:
	Electricity	13			Discounted Cash Flow	Market Price (per MWh)	(4)	10 - 403(10)	34
						Load Shaping	(8)	0% - 10%	7	%
						Usage Factor	(9)	11% - 15%	14	%
	Total assets	$	52
	Liabilities:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	16		Discounted Cash Flow	Market Price (per Dth)	(4)	(1) - 5	1
	Electricity	6			Discounted Cash Flow	Market Price (per MWh)	(4)	23 - 86	50
	FTRs(3)	16			Discounted Cash Flow	Market Price (per MWh)	(4)	(4) - 6	1
	Liquids	8			Discounted Cash Flow	Market Price (per Gal)	(4)	3-Jan	2
	Physical and Financial Options:
	Natural Gas	10			Option Model	Market Price (per Dth)	(4)	10-Mar	5
						Price Volatility	(5)	19% - 30%	23	%
						Price Correlation	(6)	(9)% - 100%	36	%
						Mean Reversion	(7)	0 - 58	4
	Total liabilities	$	56
	-1	Averages weighted by volume.
	-2	Includes basis.
	-3	Information represents Virginia Power's quantitative information about Level 3 fair value measurements.
	-4	Represents market prices beyond defined terms for Levels 1 & 2.
	-5	Represents volatilities unrepresented in published markets.
	-6	Represents intra-price correlations for which markets do not exist.
	-7	Represents mean-reverting property in price simulation modeling.
	-8	Converts block monthly loads to 24-hour load shapes.
	-9	Represents expected increase (decrease) in sales volumes compared to historical usage.
	-10	The range in market prices is the result of large variability in hourly power prices during peak and off-peak hours.
Significant unobservable inputs	'
	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)
	Mean Reversion	Buy	Increase (decrease)	Loss (gain)
	Mean Reversion	Sell	Increase (decrease)	Gain (loss)
	Load Shaping	Sell(1)	Increase (decrease)	Loss (gain)
	Usage Factor	Sell(2)	Increase (decrease)	Gain (loss)
	-1	Assumes the contract is in a gain position and load increases during peak hours.
	-2	Assumes the contract is in a gain position.
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 September 30, 2013
	Assets:
	Derivatives:
	Commodity	$	6		$	713		$	52		$	771
	Interest rate	—			114			—			114
	Investments(1):
	Equity securities:
	U.S.:
	Large cap	2,211			—			—			2,211
	Other	74			—			—			74
	Non-U.S.:
	Large cap	11			—			—			11
	Fixed income:
	Corporate debt instruments	—			352			—			352
	U.S. Treasury securities and agency debentures	414			168			—			582
	State and municipal	—			342			—			342
	Other	—			4			—			4
	Cash equivalents and other	9			80			—			89
	Restricted cash equivalents	—			10			—			10
	Total assets	$	2,725		$	1,783		$	52		$	4,560
	Liabilities:
	Derivatives:
	Commodity	$	5		$	721		$	56		$	782
	Interest rate	—			11			—			11
	Total liabilities	$	5		$	732		$	56		$	793
	At December 31, 2012
	Assets:
	Derivatives:
	Commodity	$	12		$	639		$	84		$	735
	Interest rate	—			93			—			93
	Investments(1):
	Equity securities:
	U.S.:
	Large cap	1,973			—			—			1,973
	Other	59			—			—			59
	Non-U.S.:
	Large cap	12			—			—			12
	Fixed income:
	Corporate debt instruments	—			325			—			325
	U.S. Treasury securities and agency debentures	391			152			—			543
	State and municipal	—			315			—			315
	Other	—			7			—			7
	Cash equivalents and other	13			67			—			80
	Restricted cash equivalents	—			33			—			33
	Total assets	$	2,460		$	1,631		$	84		$	4,175
	Liabilities:
	Derivatives:
	Commodity	$	8		$	528		$	59		$	595
	Interest rate	—			66			—			66
	Total liabilities	$	8		$	594		$	59		$	661
	-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 September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	(millions)
	Beginning balance	$	2		$	155		$	25		$	(71	)
	Total realized and unrealized gains (losses):
	Included in earnings	(1		)	(8		)	1			(31		)
	Included in other comprehensive income (loss)	(25		)	(48		)	11			124
	Included in regulatory assets/liabilities	10			2			(17		)	30
	Settlements	3			3			(23		)	54
	Transfers out of Level 3	7			(1		)	(1		)	(3		)
	Ending balance	$	(4	)	$	103		$	(4	)	$	103
	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	$	2		$	(15	)	$	—		$	25
Fair Value, Unobservable Inputs, Gain (Loss) Included In Earnings	'
	The following table presents Dominion's classification of gains and losses included in earnings in the Level 3 fair value category:
		Operating			Electric fuel			Total
		revenue			and other
					energy-related
					purchases
	(millions)
	Three Months Ended September 30, 2013
	Total gains (losses) included in earnings	$	5		$	(6	)	$	(1	)
	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	2			—			2
	Three Months Ended September 30, 2012
	Total gains (losses) included in earnings	$	(10	)	$	2		$	(8	)
	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	(15		)	—			(15		)
	Nine Months Ended September 30, 2013
	Total gains (losses) included in earnings	$	12		$	(11	)	$	1
	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	—			—			—
	Nine Months Ended September 30, 2012
	Total gains (losses) included in earnings	$	13		$	(44	)	$	(31	)
	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	25			—			25
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:
		30-Sep-13						31-Dec-12
		Carrying			Estimated Fair			Carrying			Estimated Fair
		Amount			Value(1)			Amount			Value(1)
	(millions)
	Dominion
	Long-term debt, including securities due within one year(2)	$	17,228		$	18,899		$	16,841		$	19,898
	Securities due within one year, VIE(3)	—			—			860			864
	Junior subordinated notes(3)	1,373			1,397			1,373			1,430
	Remarketable subordinated notes(3)	1,079			1,175			—			—
	Subsidiary preferred stock(4)	257			258			257			255
	Virginia Power
	Long-term debt, including securities due within one year(2)	$	8,039		$	8,975		$	6,669		$	8,270
	Preferred stock(4)	257			258			257			255
	-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	Carrying amount includes amounts which represent the unamortized discount and premium. At September 30, 2013 and December 31, 2012, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $56 million and $93 million, respectively.
	-3	Carrying amount includes amounts which represent the unamortized discount or premium.
	-4	Carrying amount includes deferred issuance expenses of $2 million at September 30, 2013 and December 31, 2012.
Virginia Electric and Power Company	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'
Fair Value, by Balance Sheet Grouping	'
	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 September 30, 2013
	Assets:
	Derivatives:
	Commodity	$	—		$	1		$	1		$	2
	Interest rate	—			33			—			33
	Investments(1):
	Equity securities:
	U.S.:
	Large cap	939			—			—			939
	Other	33			—			—			33
	Fixed income:
	Corporate debt instruments	—			197			—			197
	U.S. Treasury securities and agency debentures	146			63			—			209
	State and municipal	—			160			—			160
	Cash equivalents and other	—			24			—			24
	Restricted cash equivalents	—			10			—			10
	Total assets	$	1,118		$	488		$	1		$	1,607
	Liabilities:
	Derivatives:
	Commodity	$	—		$	4		$	16		$	20
	Total liabilities	$	—		$	4		$	16		$	20
	At December 31, 2012
	Assets:
	Derivatives:
	Commodity	$	—		$	1		$	5		$	6
	Investments(1):
	Equity securities:
	U.S.:
	Large cap	779			—			—			779
	Other	27			—			—			27
	Fixed income:
	Corporate debt instruments	—			196			—			196
	U.S. Treasury securities and agency debentures	168			66			—			234
	State and municipal	—			118			—			118
	Other	—			1			—			1
	Cash equivalents and other	7			31			—			38
	Restricted cash equivalents	—			10			—			10
	Total assets	$	981		$	423		$	5		$	1,409
	Liabilities:
	Derivatives:
	Commodity	$	—		$	6		$	3		$	9
	Interest rate	—			25			—			25
	Total liabilities	$	—		$	31		$	3		$	34
	-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 Virginia Power’s assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	(millions)
	Beginning balance	$	(25	)	$	1		$	2		$	(28	)
	Total realized and unrealized gains (losses):
	Included in earnings	(4		)	2			(9		)	(44		)
	Included in regulatory assets/liabilities	10			2			(17		)	31
	Settlements	4			(2		)	9			44
	Ending balance	$	(15	)	$	3		$	(15	)	$	3

Derivatives_and_Hedge_Accounti1

Derivatives and Hedge Accounting Activities (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative [Line Items]	'
Offsetting Assets	'
	The tables below present Dominion's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
		30-Sep-13									31-Dec-12
		Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	114		$	—		$	114		$	93		$	—	$	93
	Commodity contracts:
	Over-the-counter	190			—			190			290			—		290
	Exchange	568			—			568			416			—		416
	Total derivatives, subject to a master netting or similar arrangement	872			—			872			799			—		799
	Total derivatives, not subject to a master netting or similar arrangement	13			—			13			29			—		29
	Total(1)	$	885		$	—		$	885		$	828		$	—	$	828
	-1	At September 30, 2013, the total derivative asset balance contains $689 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $196 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.
					30-Sep-13											31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts			Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	114		$	11		$	—		$	103		$	93	$	19	$	—	$	74
	Commodity contracts:
	Over-the-counter	190			78			—			112			290		97		—		193
	Exchange	568			563			3			2			416		350		4		62
	Total	$	872		$	652		$	3		$	217		$	799	$	466	$	4	$	329
Offsetting Liabilities	'
		30-Sep-13									31-Dec-12
		Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	11		$	—		$	11		$	66		$	—	$	66
	Commodity contracts:
	Over-the-counter	162			—			162			191			—		191
	Exchange	617			—			617			393			—		393
	Total derivatives, subject to a master netting or similar arrangement	790			—			790			650			—		650
	Total derivatives, not subject to a master netting or similar arrangement	3			—			3			11			—		11
	Total(1)	$	793		$	—		$	793		$	661		$	—	$	661
	-1	At September 30, 2013, the total derivative liability balance contains $659 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $134 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.
					30-Sep-13											31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Paid			Net Amounts			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	11		$	11		$	—		$	—		$	66	$	19	$	—	$	47
	Commodity contracts:
	Over-the-counter	162			78			17			67			191		97		20		74
	Exchange	617			563			54			—			393		350		43		—
	Total	$	790		$	652		$	71		$	67		$	650	$	466	$	63	$	121
Volumes of Derivative Activity	'
	The following table presents the volume of Dominion’s derivative activity as of September 30, 2013. 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)	149			27
	Basis	529			379
	Electricity (MWh):
	Fixed price(1)	17,059,889			15,411,998
	FTRs	64,859,720			689,289
	Capacity (MW)	133,650			18,300
	Liquids (Gal)(2)	152,418,000			35,700,000
	Interest rate	$	2,400,000,000		$	1,150,000,000
	-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 September 30, 2013:
		AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum Term
		After-Tax
	(millions)
	Commodities:
	Gas	$	(7	)	$	(6	)	31 months
	Electricity	6			(9		)	39 months
	Other	4			2			32 months
	Interest rate	(117		)	(21		)	367 months
	Total	$	(114	)	$	(34	)
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 –			Fair Value –			Total Fair Value
		Derivatives under			Derivatives not under
		Hedge			Hedge
		Accounting			Accounting
	(millions)
	30-Sep-13
	ASSETS
	Current Assets
	Commodity	$	53		$	546		$	599
	Interest rate	90			—			90
	Total current derivative assets	143			546			689
	Noncurrent Assets
	Commodity	70			102			172
	Interest rate	24			—			24
	Total noncurrent derivative assets(1)	94			102			196
	Total derivative assets	$	237		$	648		$	885
	LIABILITIES
	Current Liabilities
	Commodity	$	64		$	584		$	648
	Interest rate	11			—			11
	Total current derivative liabilities	75			584			659
	Noncurrent Liabilities
	Commodity	47			87			134
	Total noncurrent derivative liabilities(2)	47			87			134
	Total derivative liabilities	$	122		$	671		$	793
	31-Dec-12
	ASSETS
	Current Assets
	Commodity	$	103		$	379		$	482
	Interest rate	36			—			36
	Total current derivative assets	139			379			518
	Noncurrent Assets
	Commodity	130			123			253
	Interest rate	57			—			57
	Total noncurrent derivative assets(1)	187			123			310
	Total derivative assets	$	326		$	502		$	828
	LIABILITIES
	Current Liabilities
	Commodity	$	103		$	341		$	444
	Interest rate	66			—			66
	Total current derivative liabilities	169			341			510
	Noncurrent Liabilities
	Commodity	58			93			151
	Total noncurrent derivative liabilities(2)	58			93			151
	Total derivative liabilities	$	227		$	434		$	661
	-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			Amount of Gain			Increase
		(Loss)			(Loss) Reclassified			(Decrease) in
		Recognized			from AOCI to			Derivatives
		in AOCI  on			Income			Subject to
		Derivatives						Regulatory
		(Effective						Treatment(2)
		Portion)(1)
	(millions)
	Three Months Ended September 30, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	24
	Purchased Gas				(5		)
	Electric fuel and other energy-related purchases				(3		)
	Total commodity	$	(110	)	$	16		$	4
	Interest rate(3)	(10		)	(6		)	14
	Total	$	(120	)	$	10		$	18
	Three Months Ended September 30, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	44
	Purchased gas				(9		)
	Electric fuel and other energy-related purchases				(4		)
	Total commodity	$	(128	)	$	31		$	7
	Interest rate(3)	(15		)	1			(4		)
	Total	$	(143	)	$	32		$	3
	Nine Months Ended September 30, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	(31	)
	Purchased gas				(39		)
	Electric fuel and other energy-related purchases				(6		)
	Total commodity	$	(137	)	$	(76	)	$	3
	Interest rate(3)	71			(12		)	66
	Total	$	(66	)	$	(88	)	$	69
	Nine Months Ended September 30, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	171
	Purchased gas				(55		)
	Electric fuel and other energy-related purchases				(16		)
	Total commodity	$	159		$	100		$	14
	Interest rate(3)	(91		)	2			(44		)
	Total	$	68		$	102		$	(30	)
	-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 September 30,						Nine Months Ended September 30,
	Derivatives not designated as hedging instruments	2013			2012			2013			2012
	(millions)
	Derivative Type and Location of Gains (Losses)
	Commodity
	Operating revenue	$	3		$	5		$	—		$	108
	Purchased gas	(3		)	3			(11		)	(2		)
	Electric fuel and other energy-related purchases	(12		)	3			(20		)	(33		)
	Interest rate(2)	—			10			—			17
	Total	$	(12	)	$	21		$	(31	)	$	90
	-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 Electric and Power Company	'
Derivative [Line Items]	'
Offsetting Assets	'
	The tables below present Virginia Power's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
		30-Sep-13									31-Dec-12
		Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	33		$	—		$	33		$	—		$	—	$	—
	Commodity contracts:
	Over-the-counter	2			—			2			6			—		6
	Total derivatives, subject to a master netting or similar arrangement	35			—			35			6			—		6
	Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—			—		—
	Total(1)	$	35		$	—		$	35		$	6		$	—	$	6
	-1	At September 30, 2013, the total derivative asset balance contains $35 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $6 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet.
					30-Sep-13											31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts			Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	33		$	—		$	—		$	33		$	—	$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	2			2			—			—			6		3		—		3
	Total	$	35		$	2		$	—		$	33		$	6	$	3	$	—	$	3
Offsetting Liabilities	'
		30-Sep-13									31-Dec-12
		Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	25		$	—	$	25
	Commodity contracts:
	Over-the-counter	19			—			19			7			—		7
	Exchange	1			—			1			2			—		2
	Total derivatives, subject to a master netting or similar arrangement	20			—			20			34			—		34
	Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—			—		—
	Total(1)	$	20		$	—		$	20		$	34		$	—	$	34
	-1	At September 30, 2013, the total derivative liability balance contains $20 million of current liabilities, which is presented in other current liabilities in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $33 million of current liabilities, which is presented in other current liabilities in Virginia Power’s Consolidated Balance Sheet and $1 million of noncurrent derivative liabilities, which is presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheet.
					30-Sep-13											31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet											Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Paid			Net Amounts			Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	—		$	25	$	—	$	—	$	25
	Commodity contracts:
	Over-the-counter	19			2			14			3			7		3		—		4
	Exchange	1			—			1			—			2		—		2		—
	Total	$	20		$	2		$	15		$	3		$	34	$	3	$	2	$	29
Volumes of Derivative Activity	'
	The following table presents the volume of Virginia Power’s derivative activity as of September 30, 2013. 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	9			—
	Basis	5			—
	Electricity (MWh):
	Fixed price	511,200			—
	FTRs	63,408,139			—
	Capacity (MW)	121,500			18,300
	Interest rate	$	600,000,000		$	—
Fair Value of Derivatives	'
	The following table presents the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated
	Balance Sheets:
		Fair Value –			Fair Value –			Total Fair Value
		Derivatives under			Derivatives not under
		Hedge			Hedge
		Accounting			Accounting
	(millions)
	30-Sep-13
	ASSETS
	Current Assets
	Commodity	$	1		$	1		$	2
	Interest rate	33			—			33
	Total current derivative assets(1)	34			1			35
	Total derivative assets	$	34		$	1		$	35
	LIABILITIES
	Current Liabilities
	Commodity	$	3		$	17		$	20
	Total current derivative liabilities(2)	3			17			20
	Total derivative liabilities	$	3		$	17		$	20
	31-Dec-12
	ASSETS
	Current Assets
	Commodity	$	1		$	5		$	6
	Total current derivative assets(1)	1			5			6
	Total derivative assets	$	1		$	5		$	6
	LIABILITIES
	Current Liabilities
	Commodity	$	5		$	3		$	8
	Interest rate	25			—			25
	Total current derivative liabilities(2)	30			3			33
	Noncurrent Liabilities
	Commodity	1			—			1
	Total noncurrent derivative liabilities(3)	1			—			1
	Total derivative liabilities	$	31		$	3		$	34
	-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.
Gains and Losses on Derivatives in Cash Flow Hedging Relationships	'
	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			Amount of Gain			Increase
		(Loss)			(Loss) Reclassified			(Decrease) in
		Recognized			from AOCI to			Derivatives
		in AOCI  on			Income			Subject to
		Derivatives						Regulatory
		(Effective						Treatment(2)
		Portion)(1)
	(millions)
	Three Months Ended September 30, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	(1	)
	Total commodity	$	1		$	(1	)	$	4
	Interest rate(3)	1			—			14
	Total	$	2		$	(1	)	$	18
	Three Months Ended September 30, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	(1	)
	Total commodity	$	—		$	(1	)	$	7
	Interest rate(3)	(3		)	—			(4		)
	Total	$	(3	)	$	(1	)	$	3
	Nine Months Ended September 30, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	—
	Total commodity	$	—		$	—		$	3
	Interest rate(3)	7			—			66
	Total	$	7		$	—		$	69
	Nine Months Ended September 30, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	(4	)
	Total commodity	$	(1	)	$	(4	)	$	14
	Interest rate(3)	(7		)	—			(44		)
	Total	$	(8	)	$	(4	)	$	(30	)
	-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 recorded in Virginia Power’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 September 30,						Nine Months Ended September 30,
	Derivatives not designated as hedging instruments	2013			2012			2013			2012
	(millions)
	Derivative Type and Location of Gains (Losses)
	Commodity(2)	$	(4	)	$	3		$	(8	)	$	(43	)
	Interest rate(3)	—			1			—			—
	Total	$	(4	)	$	4		$	(8	)	$	(43	)
	-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 recorded in Virginia Power's Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.
	-3	Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges.

Investments_Tables

Investments (Tables)	9 Months Ended
	Sep. 30, 2013
Gain (Loss) on Investments [Line Items]	'
Available-For-Sale Securities	'
	Dominion’s decommissioning trust funds are summarized below:
		Amortized		Total  Unrealized Gains(1)		Total  Unrealized				Fair Value
		Cost				Losses (1)
	(millions)
	30-Sep-13
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,176	$	999	$	—			$	2,175
	Other	48		20		—				68
	Marketable debt securities:
	Corporate bonds	339		17		(4		)		352
	U.S. Treasury securities and agency debentures	571		10		(7		)		574
	State and municipal	299		13		(4		)		308
	Other	4		—		—				4
	Cost method investments	103		—		—				103
	Cash equivalents and other(2)	89		—		—				89
	Total	$	2,629	$	1,059	$	(15	)	(3)	$	3,673
	December 31, 2012
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,210	$	732	$	—			$	1,942
	Other	40		13		—				53
	Marketable debt securities:
	Corporate bonds	295		30		—				325
	U.S. Treasury securities and agency debentures	523		19		(2		)		540
	State and municipal	248		26		—				274
	Other	6		1		—				7
	Cost method investments	117		—		—				117
	Cash equivalents and other(2)	72		—		—				72
	Total	$	2,511	$	821	$	(2	)	(3)	$	3,330
	-1	Included in AOCI and the decommissioning trust regulatory liability.
	-2	Includes pending sales of securities of $6 million and pending purchases of securities of $6 million at September 30, 2013 and December 31, 2012, respectively.
	-3	The fair value of securities in an unrealized loss position was $487 million and $195 million at September 30, 2013 and December 31, 2012, respectively.
Investments Classified by Contractual Maturity Date	'
	The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at September 30, 2013 by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	138
	Due after one year through five years	341
	Due after five years through ten years	358
	Due after ten years	401
	Total	$	1,238
Marketable Securities	'
	Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013			2012
	(millions)
	Proceeds from sales	$	398	$	276	$	1,260		$	1,040
	Realized gains(1)	29		15		121			71
	Realized losses(1)	13		6		29			25
	-1	Includes realized gains and losses recorded to the decommissioning trust regulatory liability.
Virginia Electric and Power Company	'
Gain (Loss) on Investments [Line Items]	'
Available-For-Sale Securities	'
	Virginia Power’s decommissioning trust funds are summarized below:
		Amortized		Total  Unrealized		Total  Unrealized				Fair Value
		Cost		Gains(1)		Losses(1)
	(millions)
	30-Sep-13
	Marketable equity securities:
	U.S.:
	Large Cap	$	505	$	433	$	—			$	938
	Other	23		10		—				33
	Marketable debt securities:
	Corporate bonds	191		9		(3		)		197
	U.S. Treasury securities and agency debentures	209		2		(2		)		209
	State and municipal	157		6		(3		)		160
	Cost method investments	103		—		—				103
	Cash equivalents and other(2)	28		—		—				28
	Total	$	1,216	$	460	$	(8	)	(3)	$	1,668
	December 31, 2012
	Marketable equity securities:
	U.S.:
	Large Cap	$	481	$	298	$	—			$	779
	Other	20		7		—				27
	Marketable debt securities:
	Corporate bonds	179		17		—				196
	U.S. Treasury securities and agency debentures	231		4		(1		)		234
	State and municipal	106		11		—				117
	Other	1		—		—				1
	Cost method investments	117		—		—				117
	Cash equivalents and other(2)	44		—		—				44
	Total	$	1,179	$	337	$	(1	)	(3)	$	1,515
	-1	Included in AOCI and the decommissioning trust regulatory liability.
	-2	Includes pending sales of securities of $4 million and $6 million at September 30, 2013 and December 31, 2012, respectively.
	-3	The fair value of securities in an unrealized loss position was $247 million and $104 million at September 30, 2013 and December 31, 2012, respectively.
Investments Classified by Contractual Maturity Date	'
	The fair value of Virginia Power’s marketable debt securities at September 30, 2013 by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	30
	Due after one year through five years	158
	Due after five years through ten years	199
	Due after ten years	179
	Total	$	566
Marketable Securities	'
	Presented below is selected information regarding Virginia Power’s marketable equity and debt securities.
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013			2012
	(millions)
	Proceeds from sales	$	140	$	128	$	464		$	481
	Realized gains(1)	8		6		34			27
	Realized losses(1)	5		2		13			9
	-1	Includes realized gains and losses recorded to the decommissioning trust regulatory liability.

Regulatory_Assets_and_Liabilit1

Regulatory Assets and Liabilities (Tables)	9 Months Ended
	Sep. 30, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule Of Regulatory Assets And Liablities	'
	Regulatory assets and liabilities include the following:
		30-Sep-13		31-Dec-12
	(millions)
	Dominion
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	72	$	55
	Derivatives(2)	18		—
	Unrecovered gas cost(3)	21		59
	Plant retirement(4)	6		25
	Other	67		64
	Regulatory assets-current(5)	184		203
	Unrecognized pension and other postretirement benefit costs(6)	934		1,210
	Deferred rate adjustment clause costs(1)	257		173
	Income taxes recoverable through future rates(7)	164		140
	Derivatives(2)	34		105
	Other	89		89
	Regulatory assets-non-current	1,478		1,717
	Total regulatory assets	$	1,662	$	1,920
	Regulatory liabilities:
	PIPP(8)	$	143	$	100
	Other	45		36
	Regulatory liabilities-current(9)	188		136
	Provision for future cost of removal and AROs(10)	1,031		985
	Decommissioning trust(11)	617		501
	Other	70		28
	Regulatory liabilities-non-current	1,718		1,514
	Total regulatory liabilities	$	1,906	$	1,650
	Virginia Power
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	72	$	51
	Derivatives(2)	18		—
	Plant retirement(4)	6		25
	Other	50		43
	Regulatory assets-current(5)	146		119
	Deferred rate adjustment clause costs(1)	204		127
	Income taxes recoverable through future rates(7)	132		110
	Derivatives(2)	34		105
	Other	50		54
	Regulatory assets-non-current	420		396
	Total regulatory assets	$	566	$	515
	Regulatory liabilities:
	Other	$	37	$	32
	Regulatory liabilities-current(9)	37		32
	Provision for future cost of removal(10)	799		763
	Decommissioning trust(11)	617		501
	Other	55		21
	Regulatory liabilities-non-current	1,471		1,285
	Total regulatory liabilities	$	1,508	$	1,317
	-1	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 12 for more information.
	-2	For jurisdictions subject to cost-based rate regulation, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they are expected to be recovered from or refunded to customers.
	-3	Reflects unrecovered gas costs at Dominion's regulated gas operations, which are recovered through annual filings with the applicable regulatory authority.
	-4	Reflects costs anticipated to be recovered in base rates for certain coal units expected to be retired.
	-5	Current regulatory assets are presented in other current assets in Dominion's and Virginia Power's Consolidated Balance Sheets.
	-6	Represents unrecognized pension and other postretirement employee benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion's rate-regulated subsidiaries.
	-7	Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes.
	-8	Under PIPP, eligible customers can receive energy assistance based on their ability to pay. The difference between the customer's total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions.
	-9	Current regulatory liabilities are presented in other current liabilities in Dominion's and Virginia Power's Consolidated Balance Sheets.
	-10	Rates charged to customers by the Companies' regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.
	-11	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power's utility nuclear generation stations, in excess of the related AROs.

Significant_Financing_Transact1

Significant Financing Transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Instrument [Line Items]	'
Schedule of Line of Credit Facilities	'
	At September 30, 2013, Dominion’s commercial paper and letters of credit outstanding, as well as its capacity available under credit facilities, were as follows:
		Facility			Outstanding			Outstanding			Facility
		Limit			Commercial			Letters of			Capacity
					Paper			Credit			Available
	(millions)
	Joint revolving credit facility(1)	$	3,000		$	2,145		$	—		$	855
	Joint revolving credit facility(2)	500			—			18			482
	Total	$	3,500		$	2,145		$	18		$	1,337
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018.  This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion of letters of credit.
	-2	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018.  Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018.  This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
Schedule of Capital Units	'
	Selected information about Dominion's Equity Units is presented below:
	Issuance Date	Units Issued		Total Net Proceeds			Total Long-term Debt			RSN Annual Interest Rate		Stock Purchase Contract Annual Rate		Stock Purchase Contract Liability		Stock Purchase Settlement Date	RSN Maturity Date
	(millions, except interest rates)
	6/7/13	11		$	533.5		$	550		1.07	%	5.055	%	$	76.7	4/1/16	4/1/21
	6/7/13	11		$	533.5		$	550		1.18	%	4.82	%	$	79.3	7/1/16	7/1/19
Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
Schedule of Line of Credit Facilities	'
	At September 30, 2013, 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			Outstanding			Outstanding			Facility
		Sub-limit			Commercial			Letters of			Sub-limit Capacity
					Paper			Credit			Available
	(millions)
	Joint revolving credit facility(1)	$	1,000		$	485		$	—		$	515
	Joint revolving credit facility(2)	250			—			1			249
	Total	$	1,250		$	485		$	1		$	764
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018.  This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (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	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018.  Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018.  This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per y

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Insurance Coverage	'
	Effective June 7, 2013 for Kewaunee and July 1, 2013 for Millstone and Virginia Power's nuclear units, the levels of nuclear property insurance coverage were reduced to the following:
		Coverage
	(billions)
	Dominion
	Millstone	$	1.7
	Kewaunee	1.06
	Virginia Power(1)
	Surry	$	1.7
	North Anna	1.7
	-1	Surry and North Anna share a blanket property limit of $450 million
Schedule Of Subsidiary Guarantees	'
	At September 30, 2013, Dominion had issued the following subsidiary guarantees:
		Stated Limit		Value(1)
	(millions)
	Subsidiary debt(2)	$	27	$	27
	Commodity transactions(3)	3,181		343
	Nuclear obligations(4)	232		55
	Cove Point(5)	335		—
	Other(6)	648		92
	Total	$	4,423	$	517
	-1	Represents the estimated portion of the guarantee's stated limit that is utilized as of September 30, 2013 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	Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, 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. The agreement for Kewaunee also provides for funds through the completion of decommissioning.
	-5	Guarantees related to Cove Point, including agreements to support terminal service and transportation agreements as well as an engineering, procurement and construction contract for new liquefaction facilities. Includes certain guarantees that do not have stated limits.
	-6	Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries' obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower.

Related_Party_Transactions_Tab

Related Party Transactions (Tables) (Virginia Electric and Power Company)	9 Months Ended
	Sep. 30, 2013
Virginia Electric and Power Company	'
Related Party Transaction [Line Items]	'
Transactions With Affiliates	'
	Presented below are significant transactions with DRS and other affiliates:
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
	(millions)
	Commodity purchases from affiliates	$	138	$	129	$	328	$	285
	Services provided by affiliates	109		107		311		298

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2013
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
		2013			2012			2013			2012
	(millions)
	Three Months Ended September 30,
	Service cost	$	31		$	29		$	10		$	11
	Interest cost	69			67			19			20
	Expected return on plan assets	(116		)	(108		)	(24		)	(19		)
	Amortization of prior service credit	—			—			(3		)	(4		)
	Amortization of net loss	37			33			2			2
	Settlements and curtailments(1)	—			—			—			(4		)
	Net periodic benefit cost	$	21		$	21		$	4		$	6
	Nine Months Ended September 30,
	Service cost	$	100		$	87		$	34		$	33
	Interest cost	202			201			56			60
	Expected return on plan assets	(345		)	(323		)	(68		)	(60		)
	Amortization of prior service cost (credit)	2			2			(9		)	(10		)
	Amortization of net loss	127			99			6			5
	Settlements and curtailments(1)(2)	(2		)	—			(15		)	(4		)
	Net periodic benefit cost	$	84		$	66		$	4		$	24
	(1) 2012 amount relates primarily to the

Goodwill_Tables

Goodwill (Tables)	9 Months Ended
	Sep. 30, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Goodwill	'
	The changes in Dominion's carrying amount and segment allocation of goodwill are presented below:
		Dominion					Dominion					DVP					Corporate and		Total
		Generation					Energy										Other
	(millions)
	Balance at December 31, 2011(1)	$	1,338				$	712				$	1,091				$	—	$	3,141
	Asset disposition adjustment	—					(11		)			—					—		(11		)
	Balance at December 31, 2012(1)	$	1,338				$	701				$	1,091				$	—	$	3,130
	Asset disposition adjustment	(16		)	(2	)	(24		)	(3	)	(3		)	(2	)	—		(43		)
	Balance at September 30, 2013(1)	$	1,322				$	677				$	1,088				$	—	$	3,087
	-1	Goodwill amounts do not contain any accumulated impairment losses.
	-2	See Note 3 in this report for a discussion of Dominion's dispositions and related goodwill write-offs.
	-3	Related to assets sold or contributed to Blue Racer.

Operating_Segments_Tables

Operating Segments (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting Information [Line Items]	'
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		Dominion			Corporate			Adjustments/Eliminations			Consolidated
					Generation(1)		Energy			and Other(1)						Total
	(millions)
	Three Months Ended September 30,
	2013
	Total revenue from external customers	$	829		$	1,882	$	361		$	(10	)	$	370		$	3,432
	Intersegment revenue	8			110		281			158			(557		)	—
	Total operating revenue	837			1,992		642			148			(187		)	3,432
	Loss from discontinued operations	—			—		—			(23		)	—			(23		)
	Net income (loss) attributable to Dominion	124			338		169			(62		)	—			569
	2012
	Total revenue from external customers	$	836		$	1,824	$	291		$	37		$	344		$	3,332
	Intersegment revenue	6			110		281			164			(561		)	—
	Total operating revenue	842			1,934		572			201			(217		)	3,332
	Loss from discontinued operations	—			—		—			(52		)	—			(52		)
	Net income (loss) attributable to Dominion	119			363		104			(377		)	—			209
	Nine Months Ended September 30,
	2013
	Total revenue from external customers	$	2,508		$	5,034	$	1,326		$	54		$	1,013		$	9,935
	Intersegment revenue	56			237		821			464			(1,578		)	—
	Total operating revenue	2,564			5,271		2,147			518			(565		)	9,935
	Loss from discontinued operations	—			—		—			(92		)	—			(92		)
	Net income (loss) attributable to Dominion	398			730		472			(334		)	—			1,266
	2012
	Total revenue from external customers	$	2,573		$	4,960	$	1,278		$	109		$	814		$	9,734
	Intersegment revenue	81			275		701			459			(1,516		)	—
	Total operating revenue	2,654			5,235		1,979			568			(702		)	9,734
	Loss from discontinued operations	—			—		—			(94		)	—			(94		)
	Net income (loss) attributable to Dominion	428			762		362			(591		)	—			961
	-1	2012 amounts have been recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
Virginia Electric and Power Company	'
Segment Reporting Information [Line Items]	'
Schedule of Segment Reporting Information, by Segment	'
	The following table presents segment information pertaining to Virginia Power’s operations:
		DVP			Dominion		Corporate			Consolidated
					Generation		and Other			Total
	(millions)
	Three Months Ended September 30,
	2013
	Operating revenue	$	470		$	1,589	$	—		$	2,059
	Net income	123			262		2			387
	2012
	Operating revenue	$	505		$	1,581	$	—		$	2,086
	Net income	128			283		4			415
	Nine Months Ended September 30,
	2013
	Operating revenue	$	1,366		$	4,184	$	—		$	5,550
	Net income (loss)	355			587		(3		)	939
	2012
	Operating revenue	$	1,413		$	4,183	$	—		$	5,596
	Net income (loss)	335			534		(39		)	830

Dispositions_Narrative_Details

Dispositions (Narrative) (Details) (USD $)	9 Months Ended	12 Months Ended	1 Months Ended		1 Months Ended	3 Months Ended	9 Months Ended	1 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Aug. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2013	Aug. 31, 2013	Sep. 30, 2013
			Elwood	Elwood	Illinois Gas Contracts	Brayton Point and Kincaid	Brayton Point and Kincaid	Other Income	Loss from Discontinued Operations
								Elwood	Brayton Point and Kincaid
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'
Sales price	'	'	'	'	$32	'	'	'	'
Gain on sale	'	'	'	'	29	'	'	'	'
After tax gain on sale	'	'	'	'	18	'	'	'	'
Write off of goodwill	43	11	'	'	3	'	'	'	16
Impairment of long-lived assets to be disposed of	'	'	'	'	'	48	'	'	'
Impairment charge, net of tax	'	'	'	'	'	28	'	'	'
Equity method investment, ownership percentage	'	'	'	50.00%	'	'	'	'	'
Proceeds from sale of Brayton Point, Kincaid and equity method investment in Elwood	'	'	465	'	'	'	'	'	'
Net gain on the sale of Brayton Point, Kincaid and equity method investment in Elwood	'	'	'	'	'	'	'	35	'
After tax gain on sale of equity method investment	'	'	'	'	'	'	'	25	'
Benefit from discontinued operations	'	'	'	'	'	'	17	'	'
Benefit from discontinued operations, net of tax	'	'	'	'	'	'	$18	'	'

Dispositions_Schedule_of_Dispo

Dispositions (Schedule of Disposal Groups, Including Discontinued Operations, Income Statement) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012
Brayton Point and Kincaid	'	'	'		'
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]	'	'	'		'
Operating revenue	$87	$77	$304		$191
Loss before income taxes	-17	-50	-135	[1]	-98
Charges related to early redemption of debt	'	'	64		'
State Line and Salem Harbor	'	'	'		'
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]	'	'	'		'
Operating revenue	'	5	'		57
Loss before income taxes	'	($19)	'		($49)
[1]	Includes $64 million of charges related to the early redemption of Brayton Point and Kincaid debt. See Note 14 in this report for more information.

Operating_Revenue_Operating_Re

Operating Revenue (Operating Revenue) (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012		Sep. 30, 2013	Sep. 30, 2012
Electric sales:	'	'		'	'
Regulated	$2,023	$2,046		$5,471	$5,495
Nonregulated	704	661		1,907	1,930
Gas sales:	'	'		'	'
Regulated	32	34		213	166
Nonregulated	159	177		712	740
Gas transportation and storage	329	297		1,156	1,007
Other	185	117		476	396
Total operating revenue	3,432	3,332	[1]	9,935	9,734	[2]
Virginia Electric and Power Company	'	'		'	'
Electric sales:	'	'		'	'
Regulated	2,023	2,046		5,471	5,495
Gas sales:	'	'		'	'
Other	36	40		79	101
Total operating revenue	$2,059	$2,086		$5,550	$5,596
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
[2]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012
		IRS	State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]	'	'	'
Period that cumulative effect of change in tax accounting is included in taxable income	'4 years	'	'
Deferred tax liabilities related to cumulative adjustments to be reflected in taxable income in 2014	'	$13	'
Reduction of valuation allowance	'	'	($20)

Income_Taxes_Reconciliation_of

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)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Operating Loss Carryforwards [Line Items]	'	'
U.S. statutory rate	35.00%	35.00%
Increases (reductions) resulting from:	'	'
State taxes, net of federal benefit	2.40%	4.40%
Investment and production tax credits	-1.80%	-0.60%
Valuation allowances	0.00%	-0.90%
AFUDC - equity	-0.70%	-0.90%
Other, net	-0.90%	-2.10%
Effective tax rate	34.00%	34.90%
Virginia Electric and Power Company	'	'
Operating Loss Carryforwards [Line Items]	'	'
U.S. statutory rate	35.00%	35.00%
Increases (reductions) resulting from:	'	'
State taxes, net of federal benefit	2.80%	3.90%
Investment and production tax credits	-0.20%	0.00%
Valuation allowances	0.00%	0.00%
AFUDC - equity	-1.10%	-0.80%
Other, net	-0.30%	0.10%
Effective tax rate	36.20%	38.20%

Income_Taxes_Schedule_of_Unrec

Income Taxes (Schedule of Unrecognized Tax Benefits) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'
Balance at January 1, 2013	$231	$293
Increases - prior period positions	14	'
Decreases - prior period positions	-91	'
Current period positions	21	'
Settlements	-2	'
Expiration of statutes of limitations	-4	'
Balance at September 30, 2013	231	293
Virginia Electric and Power Company	'	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'
Balance at January 1, 2013	32	57
Increases - prior period positions	12	'
Decreases - prior period positions	-42	'
Current period positions	7	'
Settlements	-2	'
Expiration of statutes of limitations	0	'
Balance at September 30, 2013	$32	$57

Earnings_Per_Share_Calculation

Earnings Per Share (Calculation of Our Basic and Diluted EPS) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Earnings Per Share [Abstract]	'		'		'		'
Net income attributable to Dominion	$569		$209	[1],[2]	$1,266		$961	[1]
Average shares of common stock outstanding - Basic (shares)	579,400,000		573,800,000		578,100,000		572,100,000
Net effect of potentially dilutive securities (shares)	700,000	[3]	900,000	[3]	700,000	[3]	1,100,000	[3]
Average shares of common stock outstanding - Diluted (shares)	580,100,000		574,700,000		578,800,000		573,200,000
Earnings Per Common Share - Basic (dollars per share)	$0.98		$0.36	[2]	$2.19		$1.68	[1]
Earnings Per Common Share - Diluted (dollars per share)	$0.98		$0.36	[2]	$2.19		$1.68	[1]
Potentially dilutive securities excluded from computation of earnings per share (shares)	'		'		0		0
[1]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[2]	Recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
[3]	Dilutive securities consist primarily of contingently convertible senior notes. See Note 14 in this report for more information.

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income (Schedule of Changes in AOCI by Component Net of Tax) (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'		'	'		'
Beginning balance	($483)		'	($877)	[1]	'
Other comprehensive income before reclassifications: gains (losses)	-51		'	290		'
Amounts reclassified from accumulated other comprehensive income (loss): (gains) losses	-2	[2]	'	51	[2]	'
Total other comprehensive income (loss)	-53		-52	341		103
Ending balance	-536		'	-536		'
Deferred gains and losses on derivatives-hedging activities	'		'	'		'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'		'	'		'
Beginning balance	-31		'	-122		'
Other comprehensive income before reclassifications: gains (losses)	-77		'	-45		'
Amounts reclassified from accumulated other comprehensive income (loss): (gains) losses	-6	[2]	'	53	[2]	'
Total other comprehensive income (loss)	-83		'	8		'
Ending balance	-114		'	-114		'
Unrealized gains and losses on investment securities	'		'	'		'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'		'	'		'
Beginning balance	371		'	326		'
Other comprehensive income before reclassifications: gains (losses)	38		'	119		'
Amounts reclassified from accumulated other comprehensive income (loss): (gains) losses	-10	[2]	'	-46	[2]	'
Total other comprehensive income (loss)	28		'	73		'
Ending balance	399		'	399		'
Unrecognized pension and other postretirement benefit costs	'		'	'		'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'		'	'		'
Beginning balance	-823		'	-1,081		'
Other comprehensive income before reclassifications: gains (losses)	-12		'	216		'
Amounts reclassified from accumulated other comprehensive income (loss): (gains) losses	14	[2]	'	44	[2]	'
Total other comprehensive income (loss)	2		'	260		'
Ending balance	($821)		'	($821)		'
[1]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[2]	See table below for details about these reclassifications.

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Income (Schedule of Reclassifications out of AOCI by Component Net of Tax) (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012		Sep. 30, 2013	Sep. 30, 2012
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'		'	'
Operating Revenue	$3,432	$3,332	[1]	$9,935	$9,734	[2]
Purchased gas	232	191	[1]	996	818	[2]
Electric fuel and other energy-related purchases	1,107	1,009	[1]	2,933	2,816	[2]
Interest and related charges	217	197	[1]	648	618	[2]
Other income	86	56	[1]	222	174	[2]
Income from continuing operations including noncontrolling interests before income tax expense	903	410	[1]	2,086	1,653	[2]
Income tax expense	-305	-143	[1]	-709	-578	[2]
Income from continuing operations including noncontrolling interests	598	267	[1]	1,377	1,075	[2]
Deferred gains and losses on derivatives-hedging activities | Amounts reclassified from AOCI	'	'		'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'		'	'
Income from continuing operations including noncontrolling interests before income tax expense	-10	'		88	'
Income tax expense	4	'		-35	'
Income from continuing operations including noncontrolling interests	-6	'		53	'
Unrealized gains and losses on investment securities | Amounts reclassified from AOCI	'	'		'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'		'	'
Other income	-16	'		-80	'
Impairment	1	'		6	'
Income from continuing operations including noncontrolling interests before income tax expense	-15	'		-74	'
Income tax expense	5	'		28	'
Income from continuing operations including noncontrolling interests	-10	'		-46	'
Unrecognized pension and other postretirement benefit costs | Amounts reclassified from AOCI	'	'		'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'		'	'
Prior service costs	'	'		-6	'
Actuarial losses	23	'		79	'
Income from continuing operations including noncontrolling interests before income tax expense	23	'		73	'
Income tax expense	-9	'		-29	'
Income from continuing operations including noncontrolling interests	14	'		44	'
Commodity contracts | Deferred gains and losses on derivatives-hedging activities | Amounts reclassified from AOCI	'	'		'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'		'	'
Operating Revenue	-24	'		31	'
Purchased gas	5	'		39	'
Electric fuel and other energy-related purchases	3	'		6	'
Interest rate contracts | Deferred gains and losses on derivatives-hedging activities | Amounts reclassified from AOCI	'	'		'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'		'	'
Interest and related charges	$6	'		$12	'
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
[2]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.

Fair_Value_Measurements_Fair_V

Fair Value Measurements Fair Value Measurements (Narrative) (Details) (USD $)	9 Months Ended		1 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Jun. 30, 2013	Sep. 30, 2013
			Gas, Transmission and Distribution Equipment	Gas, Transmission and Distribution Equipment
				Fair Value, Measurements, Nonrecurring
				Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Impairment of merchant generation assets	$48	$444	$49	'
Impairment charge for certain natural gas infrastructure facilities, net of tax	'	'	29	'
Estimated fair value (less than $1 million)	'	'	'	$1

Fair_Value_Measurements_Fair_V1

Fair Value Measurements Fair Value, Option, Quantitative Disclosures (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Natural Gas

Natural Gas

Electricity

Electricity

FTRs(3)

Liquids

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Full Requirements Contracts:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Natural Gas

Natural Gas

Natural Gas

Natural Gas

Natural Gas

Natural Gas

Electricity

Electricity

Electricity

Electricity

Electricity

Electricity

FTRs(3)

FTRs(3)

FTRs(3)

Liquids

Liquids

Liquids

Natural Gas

Natural Gas

Natural Gas

Natural Gas

Natural Gas

Natural Gas

Electricity

Electricity

Electricity

FTRs(3)

FTRs(3)

FTRs(3)

Liquids

Liquids

Liquids

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Options:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Full Requirements Contracts:

Full Requirements Contracts:

Full Requirements Contracts:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Options:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Minimum

Maximum

Wieghted Average

Minimum

Maximum

Wieghted Average

Minimum

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Wieghted Average

Minimum

Maximum

Wieghted Average

Minimum

Maximum

Wieghted Average

Minimum

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Wieghted Average

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Wieghted Average

Minimum

Maximum

Wieghted Average

Minimum

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Wieghted Average

Minimum

Maximum

Wieghted Average

Minimum

Maximum

Wieghted Average

Fair Value, Option, Quantitative Disclosures [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Derivative Assets

$885,000,000

[1]

$828,000,000

[1]

$52,000,000

$10,000,000

[2]

$7,000,000

$9,000,000

$13,000,000

$1,000,000

[3]

$12,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Derivative Liabilities

793,000,000

[4]

661,000,000

[4]

56,000,000

16,000,000

[2]

10,000,000

6,000,000

'

16,000,000

[3]

8,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Market Price (per unit)

'

'

'

'

'

'

'

'

'

-1

[5]

5

[5]

2

[5],[6]

3

[5]

5

[5]

4

[5],[6]

31

[5]

77

[5],[7]

44

[5],[6]

10

[7]

403

[7]

34

[5],[6]

-1

[5]

6

[5]

0

[5],[6]

0

[5]

3

[5]

1

[5],[6]

-1

[5]

5

[5]

1

[5],[6]

3

[5]

10

[5]

5

[5],[6]

23

[5]

86

[5]

50

[5],[6]

-4

[5]

6

[5]

1

[5],[6]

1

[5]

3

[5]

2

[5],[6]

Price Volatility (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

19.00%

[8]

30.00%

[8]

24.00%

[6],[8]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

19.00%

[8]

30.00%

[8]

23.00%

[6],[8]

'

'

'

'

'

'

'

'

'

Price Correlation (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

-9.00%

[9]

100.00%

[9]

36.00%

[6],[9]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-9.00%

[9]

100.00%

[9]

36.00%

[6],[9]

'

'

'

'

'

'

'

'

'

Mean Reversion (per unit)

'

'

'

'

'

'

'

'

'

'

'

'

$0

[10]

$58

[10]

$4

[10],[6]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

[10]

$58

[10]

$4

[10],[6]

'

'

'

'

'

'

'

'

'

Load Shaping (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

[11]

10.00%

[11]

7.00%

[11],[6]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Usage Factor (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11.00%

[12]

15.00%

[12]

14.00%

[12],[6]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

At September 30, 2013, the total derivative asset balance contains $689 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $196 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.

[2]

Includes basis.

[3]

Information represents Virginia Power's quantitative information about Level 3 fair value measurements.

[4]

At September 30, 2013, the total derivative liability balance contains $659 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $134 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.

[5]

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

[6]

Averages weighted by volume.

[7]

The range in market prices is the result of large variability in hourly power prices during peak and off-peak hours.

[8]

Represents volatilities unrepresented in published markets.

[9]

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

[10]

Represents mean-reverting property in price simulation modeling.

[11]

Converts block monthly loads to 24-hour load shapes.

[12]

Represents expected increase (decrease) in sales volumes compared to historical usage.

Fair_Value_Measurements_Assets

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	$885	[1]	$828	[1]
Derivative Liabilities	793	[2]	661	[2]
Level 3	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	52		'
Derivative Liabilities	56		'
Fair Value, Measurements, Recurring	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	4,560		4,175
Total liabilities	793		661
Fair Value, Measurements, Recurring | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	771		735
Derivative Liabilities	782		595
Fair Value, Measurements, Recurring | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	114		93
Derivative Liabilities	11		66
Fair Value, Measurements, Recurring | Equity securities: | Large cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	2,211	[3]	1,973	[3]
Fair Value, Measurements, Recurring | Equity securities: | Large cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	11	[3]	12	[3]
Fair Value, Measurements, Recurring | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	74	[3]	59	[3]
Fair Value, Measurements, Recurring | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	352	[3]	325	[3]
Fair Value, Measurements, Recurring | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	582	[3]	543	[3]
Fair Value, Measurements, Recurring | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	342	[3]	315	[3]
Fair Value, Measurements, Recurring | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	4	[3]	7	[3]
Fair Value, Measurements, Recurring | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	89		80
Fair Value, Measurements, Recurring | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	10		33
Fair Value, Measurements, Recurring | Level 1	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	2,725		2,460
Total liabilities	5		8
Fair Value, Measurements, Recurring | Level 1 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	6		12
Derivative Liabilities	5		8
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 | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	2,211	[3]	1,973	[3]
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	11	[3]	12	[3]
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	74	[3]	59	[3]
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	414	[3]	391	[3]
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	9		13
Fair Value, Measurements, Recurring | Level 1 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0		0
Fair Value, Measurements, Recurring | Level 2	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	1,783		1,631
Total liabilities	732		594
Fair Value, Measurements, Recurring | Level 2 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	713		639
Derivative Liabilities	721		528
Fair Value, Measurements, Recurring | Level 2 | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	114		93
Derivative Liabilities	11		66
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	352	[3]	325	[3]
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	168	[3]	152	[3]
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	342	[3]	315	[3]
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	4	[3]	7	[3]
Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	80		67
Fair Value, Measurements, Recurring | Level 2 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	10		33
Fair Value, Measurements, Recurring | Level 3	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	52		84
Total liabilities	56		59
Fair Value, Measurements, Recurring | Level 3 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	52		84
Derivative Liabilities	56		59
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 | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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		0
Fair Value, Measurements, Recurring | Level 3 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0		0
Virginia Electric and Power Company	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	35	[1]	6	[1]
Derivative Liabilities	20	[2]	34	[2]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	1,607	[3]	1,409	[3]
Total liabilities	20		34
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	2		6
Derivative Liabilities	20		9
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	33		'
Derivative Liabilities	'		25
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | Large cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	939	[3]	779	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	33	[3]	27	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	197	[3]	196	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	209	[3]	234	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	160	[3]	118	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	'		1	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	24	[3]	38	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	10	[3]	10	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	1,118	[3]	981	[3]
Total liabilities	0		0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	0		0
Derivative Liabilities	0		0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	0		'
Derivative Liabilities	'		0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	939	[3]	779	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	33	[3]	27	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	146	[3]	168	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	'		0	[3]
Virginia Electric and Power Company | 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	[3]	7	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	488	[3]	423	[3]
Total liabilities	4		31
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	1		1
Derivative Liabilities	4		6
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	33		'
Derivative Liabilities	'		25
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	197	[3]	196	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	63	[3]	66	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	160	[3]	118	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	'		1	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	24	[3]	31	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	10	[3]	10	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	1	[3]	5	[3]
Total liabilities	16		3
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	1		5
Derivative Liabilities	16		3
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	0		'
Derivative Liabilities	'		0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Other Equity Securities [Member] | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	'		0	[3]
Virginia Electric and Power Company | 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	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	$0	[3]	$0	[3]
[1]	At September 30, 2013, the total derivative asset balance contains $689 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $196 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.
[2]	At September 30, 2013, the total derivative liability balance contains $659 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $134 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.
[3]	Includes investments held in the nuclear decommissioning and rabbi trusts.

Fair_Value_Measurements_Net_Ch

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 $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Total realized and unrealized gains (losses):	'	'	'	'
Included in earnings	($1)	($8)	$1	($31)
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	2	-15	0	25
Level 3 | Commodity Transactions | Fair Value, Measurements, Recurring	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'
Beginning balance	2	155	25	-71
Total realized and unrealized gains (losses):	'	'	'	'
Included in earnings	-1	-8	1	-31
Included in other comprehensive income (loss)	-25	-48	11	124
Included in regulatory assets/liabilities	10	2	-17	30
Settlements	3	3	-23	54
Transfers out of Level 3	7	-1	-1	-3
Ending balance	-4	103	-4	103
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	2	-15	0	25
Level 3 | Virginia Electric and Power Company | Commodity Transactions | Fair Value, Measurements, Recurring	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'
Beginning balance	-25	1	2	-28
Total realized and unrealized gains (losses):	'	'	'	'
Included in earnings	-4	2	-9	-44
Included in regulatory assets/liabilities	10	2	-17	31
Settlements	4	-2	9	44
Ending balance	($15)	$3	($15)	$3

Fair_Value_Measurements_Gains_

Fair Value Measurements (Gains and Losses Included in Earnings in the Level 3 Fair Value Category) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total gains (losses) included in earnings	($1)	($8)	$1	($31)
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	2	-15	0	25
Operating revenue	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total gains (losses) included in earnings	5	-10	12	13
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	2	-15	0	25
Electric fuel and other energy-related purchases	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total gains (losses) included in earnings	-6	2	-11	-44
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	$0	$0

Fair_Value_Measurements_Financ

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Details) (USD $)	9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Junior subordinated notes	$1,373		$1,373	[1]
Subsidiary preferred stock	257		257	[1]
Valuation of certain fair value hedges	56		93
Issuance expenses of subsidiary preferred stock	2		2
Carrying Amount	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Total Long-term Debt	17,228	[2]	16,841	[2]
Securities due within one year, VIE	0	[3]	860	[3]
Junior subordinated notes	1,373	[3]	1,373	[3]
Remarketable subordinated notes	1,079	[3]	0	[3]
Subsidiary preferred stock	257	[4]	257	[4]
Estimate of Fair Value	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Total Long-term Debt	18,899	[2],[5]	19,898	[2],[5]
Securities due within one year, VIE	0	[3],[5]	864	[3],[5]
Junior subordinated notes	1,397	[3],[5]	1,430	[3],[5]
Remarketable subordinated notes	1,175	[3],[5]	0	[3],[5]
Subsidiary preferred stock	258	[4],[5]	255	[4],[5]
Virginia Electric and Power Company	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Subsidiary preferred stock	257		257	[6]
Virginia Electric and Power Company | Carrying Amount	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Total Long-term Debt	8,039	[2]	6,669	[2]
Subsidiary preferred stock	257	[4]	257	[4]
Virginia Electric and Power Company | Estimate of Fair Value	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Total Long-term Debt	8,975	[2],[5]	8,270	[2],[5]
Subsidiary preferred stock	$258	[4],[5]	$255	[4],[5]
[1]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[2]	Carrying amount includes amounts which represent the unamortized discount and premium. At September 30, 2013 and December 31, 2012, includes the valuation of certain fair value hedges associated with Dominion’s fixed rate debt of approximately $56 million and $93 million, respectively.
[3]	Carrying amount includes amounts which represent the unamortized discount or premium.
[4]	Carrying amount includes deferred issuance expenses of $2 million at September 30, 2013 and December 31, 2012.
[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.
[6]	Virginia Power’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.

Derivatives_and_Hedge_Accounti2

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	$872		$799
Total derivatives, not subject to a master netting or similar arrangement	13		29
Derivative Assets	885	[1]	828	[1]
Gross Amounts Offset in the Consolidated Balance Sheet	0	[1]	0	[1]
Financial Instruments	652		466
Cash Collateral Received	3		4
Net Amounts	217		329
Derivative assets	689		518	[2]
Current Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets	689		'
Current Derivative Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets	'		518
Non Current Derivative Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets, noncurrent	196		310
Interest rate | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	114		93
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Financial Instruments	11		19
Cash Collateral Received	0		0
Net Amounts	103		74
Commodity | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	190		290
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Financial Instruments	78		97
Cash Collateral Received	0		0
Net Amounts	112		193
Commodity | Exchange	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	568		416
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Financial Instruments	563		350
Cash Collateral Received	3		4
Net Amounts	2		62
Virginia Electric and Power Company	'		'
Offsetting Assets [Line Items]	'		'
Total derivatives, not subject to a master netting or similar arrangement	0		0
Derivative Assets	35	[1]	6	[1]
Gross Amounts Offset in the Consolidated Balance Sheet	0	[1]	0	[1]
Virginia Electric and Power Company | Current Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets	35		6
Virginia Electric and Power Company | Interest rate | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	33		0
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Financial Instruments	0		0
Cash Collateral Received	0		0
Net Amounts	33		0
Virginia Electric and Power Company | Commodity | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	2		6
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Financial Instruments	2		3
Cash Collateral Received	0		0
Net Amounts	0		3
Virginia Electric and Power Company | Commodity | Exchange	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	35		6
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Financial Instruments	2		3
Cash Collateral Received	0		0
Net Amounts	$33		$3
[1]	At September 30, 2013, the total derivative asset balance contains $689 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $196 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.
[2]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.

Derivatives_and_Hedge_Accounti3

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	$790		$650
Total derivatives, not subject to a master netting or similar arrangement	3		11
Financial Instruments	652		466
Cash Collateral Paid	71		63
Net Amounts	67		121
Derivative liabilities	659		510	[1]
Gross Amounts Offset in the Consolidated Balance Sheet	0	[2]	0	[2]
Derivative Liabilities	793	[2]	661	[2]
Current Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative liabilities	659		510
Non Current Derivative Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative liabilities, noncurrent	134		151
Interest rate | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	11		66
Financial Instruments	11		19
Cash Collateral Paid	0		0
Net Amounts	0		47
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Commodity | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	162		191
Financial Instruments	78		97
Cash Collateral Paid	17		20
Net Amounts	67		74
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Commodity | Exchange	'		'
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	617		393
Financial Instruments	563		350
Cash Collateral Paid	54		43
Net Amounts	0		0
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Virginia Electric and Power Company	'		'
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	20		34
Total derivatives, not subject to a master netting or similar arrangement	0		0
Financial Instruments	2		3
Cash Collateral Paid	15		2
Net Amounts	3		29
Gross Amounts Offset in the Consolidated Balance Sheet	0	[2]	0	[2]
Derivative Liabilities	20	[2]	34	[2]
Virginia Electric and Power Company | Current Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative liabilities	20		33
Virginia Electric and Power Company | Non Current Derivative Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative liabilities, noncurrent	'		1
Virginia Electric and Power Company | Interest rate | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	0		25
Financial Instruments	0		0
Cash Collateral Paid	0		0
Net Amounts	0		25
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Virginia Electric and Power Company | Commodity | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	19		7
Financial Instruments	2		3
Cash Collateral Paid	14		0
Net Amounts	3		4
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Virginia Electric and Power Company | Commodity | Exchange	'		'
Offsetting Liabilities [Line Items]	'		'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	1		2
Financial Instruments	0		0
Cash Collateral Paid	1		2
Net Amounts	0		0
Gross Amounts Offset in the Consolidated Balance Sheet	$0		$0
[1]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[2]	At September 30, 2013, the total derivative liability balance contains $659 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $134 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.

Derivatives_and_Hedge_Accounti4

Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Current Derivative Contract	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	$2,400
Current Derivative Contract | Natural Gas | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	149,000,000,000	[1]
Current Derivative Contract | Natural Gas | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	529,000,000,000
Current Derivative Contract | Electricity | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	17,059,889	[1]
Current Derivative Contract | Electricity | Financial Transmission Rights	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	64,859,720
Current Derivative Contract | Capacity	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity (MW)	133,650
Current Derivative Contract | Liquids	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	152,418,000	[2]
Noncurrent Derivative Contract	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	1,150
Noncurrent Derivative Contract | Natural Gas | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	27,000,000,000	[1]
Noncurrent Derivative Contract | Natural Gas | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	379,000,000,000
Noncurrent Derivative Contract | Electricity | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	15,411,998	[1]
Noncurrent Derivative Contract | Electricity | Financial Transmission Rights	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	689,289
Noncurrent Derivative Contract | Capacity	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity (MW)	18,300
Noncurrent Derivative Contract | Liquids	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	35,700,000	[2]
Virginia Electric and Power Company | Current Derivative Contract	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	600
Virginia Electric and Power Company | Current Derivative Contract | Natural Gas | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	9,000,000,000
Virginia Electric and Power Company | Current Derivative Contract | Natural Gas | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	5,000,000,000
Virginia Electric and Power Company | Current Derivative Contract | Electricity | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	511,200
Virginia Electric and Power Company | Current Derivative Contract | Electricity | Financial Transmission Rights	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	63,408,139
Virginia Electric and Power Company | Current Derivative Contract | Capacity	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity (MW)	121,500
Virginia Electric and Power Company | Noncurrent Derivative Contract	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	$0
Virginia Electric and Power Company | Noncurrent Derivative Contract | Natural Gas | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	0
Virginia Electric and Power Company | Noncurrent Derivative Contract | Natural Gas | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (cf)/ liquids (gallons)	0
Virginia Electric and Power Company | Noncurrent Derivative Contract | Electricity | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	0
Virginia Electric and Power Company | Noncurrent Derivative Contract | Electricity | Financial Transmission Rights	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (MWh)	0
Virginia Electric and Power Company | Noncurrent Derivative Contract | Capacity	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity (MW)	18,300
[1]	Includes options.
[2]	Includes NGLs and oil.

Derivatives_and_Hedge_Accounti5

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'
AOCI After-Tax	($114)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	-34
Commodity | Gas Energy Contract	'
Derivative Instruments, Gain (Loss) [Line Items]	'
AOCI After-Tax	-7
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	-6
Maximum Term	'31 months
Commodity | Electricity Energy Contract	'
Derivative Instruments, Gain (Loss) [Line Items]	'
AOCI After-Tax	6
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	-9
Maximum Term	'39 months
Commodity | Other Energy Contract	'
Derivative Instruments, Gain (Loss) [Line Items]	'
AOCI After-Tax	4
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	2
Maximum Term	'32 months
Interest rate	'
Derivative Instruments, Gain (Loss) [Line Items]	'
AOCI After-Tax	-117
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	($21)
Maximum Term	'367 months

Derivatives_and_Hedge_Accounti6

Derivatives and Hedge Accounting Activities (Fair Value of Derivatives) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	$885		$828
Total Fair Value, Liabilities	793		661
Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	689		518
Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	599		482
Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	90		36
Noncurrent Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	196	[1]	310	[1]
Noncurrent Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	172		253
Noncurrent Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	24		57
Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	659		510
Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	648		444
Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	11		66
Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	134	[2]	151	[2]
Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	134		151
Fair Value – Derivatives under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	237		326
Total Fair Value, Liabilities	122		227
Fair Value – Derivatives under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	143		139
Fair Value – Derivatives under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	53		103
Fair Value – Derivatives under Hedge Accounting | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	90		36
Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	94	[1]	187	[1]
Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	70		130
Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	24		57
Fair Value – Derivatives under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	75		169
Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	64		103
Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	11		66
Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	47	[2]	58	[2]
Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	47		58
Fair Value – Derivatives not under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	648		502
Total Fair Value, Liabilities	671		434
Fair Value – Derivatives not under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	546		379
Fair Value – Derivatives not under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	546		379
Fair Value – Derivatives not under Hedge Accounting | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	0		0
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	102	[1]	123	[1]
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	102		123
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	0		0
Fair Value – Derivatives not under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	584		341
Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	584		341
Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	0		0
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	87	[2]	93	[2]
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	87		93
Virginia Electric and Power Company	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	35		6
Total Fair Value, Liabilities	'		34
Virginia Electric and Power Company | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	35	[3]	6	[3]
Virginia Electric and Power Company | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	2		6
Virginia Electric and Power Company | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	33		'
Virginia Electric and Power Company | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	20		33	[4]
Virginia Electric and Power Company | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	20		8
Virginia Electric and Power Company | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		25
Virginia Electric and Power Company | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1	[5]
Virginia Electric and Power Company | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	34		1
Total Fair Value, Liabilities	'		31
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	34	[3]	1	[3]
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	1		1
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	33		'
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	3		30	[4]
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	3	[4]	5
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		25
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1	[5]
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	1		5
Total Fair Value, Liabilities	'		3
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	1	[3]	5	[3]
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	1		5
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	0		'
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	17		3	[4]
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	17		3
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		0
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		0	[5]
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		$0
[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.
[3]	Current derivative assets are presented in other current assets in Virginia Power's Consolidated Balance Sheets.
[4]	Current derivative liabilities are presented in other current liabilities in Virginia Power's Consolidated Balance Sheets.
[5]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.

Derivatives_and_Hedge_Accounti7

Derivatives and Hedge Accounting Activities (Gains and Losses on Derivatives in Cash Flow Hedging Relationships) (Details) (Cash Flow Hedges, USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	($120)	[1]	($143)	[1]	($66)	[1]	$68	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	10		32		-88		102
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	18	[2]	3	[2]	69	[2]	-30	[2]
Commodity	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	-110	[1]	-128	[1]	-137	[1]	159	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	16		31		-76		100
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	4	[2]	7	[2]	3	[2]	14	[2]
Commodity | Operating revenue	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	24		44		-31		171
Commodity | Purchased gas	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	-5		-9		-39		-55
Commodity | Electric fuel and other energy-related purchases	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	-3		-4		-6		-16
Interest rate	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	-10	[1],[3]	-15	[1],[3]	71	[1],[3]	-91	[1],[3]
Amount of Gain (Loss) Reclassified from AOCI to Income	-6	[3]	1	[3]	-12	[3]	2	[3]
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	14	[2],[3]	-4	[2],[3]	66	[2],[3]	-44	[2],[3]
Virginia Electric and Power Company	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	2	[4]	-3	[4]	7	[4]	-8	[4]
Amount of Gain (Loss) Reclassified from AOCI to Income	-1		-1		0		-4
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	18	[5]	3	[5]	69	[5]	-30	[5]
Virginia Electric and Power Company | Commodity	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	1	[4]	0	[4]	0	[4]	-1	[4]
Amount of Gain (Loss) Reclassified from AOCI to Income	-1		-1		0		-4
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	4	[5]	7	[5]	3	[5]	14	[5]
Virginia Electric and Power Company | Commodity | Electric fuel and other energy-related purchases	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	-1		-1		0		-4
Virginia Electric and Power Company | Interest rate	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	1	[4],[6]	-3	[4],[6]	7	[4],[6]	-7	[4],[6]
Amount of Gain (Loss) Reclassified from AOCI to Income	0	[6]	0	[6]	0	[6]	0	[6]
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	$14	[5],[6]	($4)	[5],[6]	$66	[5],[6]	($44)	[5],[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.
[4]	Amounts deferred into AOCI have no associated effect in Virginia Power’s Consolidated Statements of Income.
[5]	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.
[6]	Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges.

Derivatives_and_Hedge_Accounti8

Derivatives and Hedge Accounting Activities (Schedule of Derivatives not Designated as Hedging Instruments) (Details) (Fair Value - Derivatives not under Hedge Accounting, USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	($12)	[1]	$21	[1]	($31)	[1]	$90	[1]
Interest rate	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	0	[1],[2]	10	[1],[2]	'		'
Commodity | Operating revenue	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	3	[1]	5	[1]	0	[1]	108	[1]
Commodity | Purchased gas	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-3	[1]	3	[1]	-11	[1]	-2	[1]
Commodity | Electric fuel and other energy-related purchases	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-12	[1]	3	[1]	-20	[1]	-33	[1]
Interest rate | Interest rate	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	'		'		0	[1],[2]	17	[1],[2]
Virginia Electric and Power Company	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-4	[3]	4	[3]	-8	[3]	-43	[3]
Virginia Electric and Power Company | Interest rate	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	0	[3],[4]	1	[3],[4]	'		'
Virginia Electric and Power Company | Commodity | Electric fuel and other energy-related purchases	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-4	[3],[5]	3	[3],[5]	-8	[3],[5]	-43	[3],[5]
Virginia Electric and Power Company | Interest rate | Interest rate	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	'		'		$0	[3],[4]	$0	[3],[4]
[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.
[3]	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.
[4]	Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges
[5]	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.

Investments_Narrative_Details

Investments (Narrative) (Details) (USD $)	9 Months Ended		3 Months Ended	1 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Mar. 31, 2013	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012
			Blue Racer	Blue Racer	Blue Racer	Categories of Investments, Marketable Securities, Trading Securities	Categories of Investments, Marketable Securities, Trading Securities	Cost method investments	Cost method investments
				Line TL-404	Line TL-404
Gain (Loss) on Investments [Line Items]	'	'	'	'	'	'	'	'	'
Assets Held-in-trust	'	'	'	'	'	$100	$95	$10	$14
Cash proceeds from sale of assets	595	0	'	47	83	'	'	'	'
Gain on sale of assets	'	'	'	25	75	'	'	'	'
After tax gain on sale of assets	'	'	'	14	42	'	'	'	'
Contribution of assets in exchange for additional ownership interest in Blue Racer	$473	$0	$473	'	'	'	'	'	'

Investments_Marketable_Equity_

Investments (Marketable Equity and Debt Securities and Cash Equivalents (Classified as Available-for-sale) and Cost Method Investments in Decommissioning Trust Funds) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Investment Holdings [Line Items]	'		'
Amortized Cost, Total	$2,629		$2,511
Total Unrealized Gains	1,059	[1]	821	[1]
Total Unrealized Losses	-15	[1],[2]	-2	[1],[2]
Fair Value	3,673		3,330	[3]
Net assets related to pending sales and purchases of securities	6		6
Fair Value of securities in an unrealized loss position	487		195
Cost method investments	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Other Investments	103		117
Total Unrealized Gains	0	[1]	0	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	103		117
Cash Equivalents and Other Investment	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Other Investments	89	[4]	72	[4]
Total Unrealized Gains	0	[1],[4]	0	[1],[4]
Total Unrealized Losses	0	[1],[4]	0	[1],[4]
Fair Value	89	[4]	72	[4]
Equity Securities | Large Cap | United States	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	1,176		1,210
Total Unrealized Gains	999	[1]	732	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	2,175		1,942
Equity Securities | Other | United States	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	48		40
Total Unrealized Gains	20	[1]	13	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	68		53
Corporate bonds	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	339		295
Total Unrealized Gains	17	[1]	30	[1]
Total Unrealized Losses	-4	[1]	0	[1]
Fair Value	352		325
U.S. Treasury securities and agency debentures	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	571		523
Total Unrealized Gains	10	[1]	19	[1]
Total Unrealized Losses	-7	[1]	-2	[1]
Fair Value	574		540
State and municipal	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	299		248
Total Unrealized Gains	13	[1]	26	[1]
Total Unrealized Losses	-4	[1]	0	[1]
Fair Value	308		274
Other	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	4		6
Total Unrealized Gains	0	[1]	1	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	4		7
Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Total	1,216		1,179
Total Unrealized Gains	460	[1]	337	[1]
Total Unrealized Losses	-8	[1],[5]	-1	[1],[5]
Fair Value	1,668		1,515	[6]
Net assets related to pending sales and purchases of securities	4		6
Fair Value of securities in an unrealized loss position	247		104
Virginia Electric and Power Company | Cost method investments	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Other Investments	103		117
Total Unrealized Gains	0	[1]	0	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	103		117
Virginia Electric and Power Company | Cash Equivalents and Other Investment	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Other Investments	28	[7]	44	[7]
Total Unrealized Gains	0	[1],[7]	0	[1],[7]
Total Unrealized Losses	0	[1],[7]	0	[1],[7]
Fair Value	28	[7]	44	[7]
Virginia Electric and Power Company | Equity Securities | Large Cap | United States	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	505		481
Total Unrealized Gains	433	[1]	298	[1]
Total Unrealized Losses	0	[1]	'
Fair Value	938		779
Virginia Electric and Power Company | Equity Securities | Other | United States	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	23		20
Total Unrealized Gains	10	[1]	7	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	33		27
Virginia Electric and Power Company | Corporate bonds	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	191		179
Total Unrealized Gains	9	[1]	17	[1]
Total Unrealized Losses	-3	[1]	0	[1]
Fair Value	197		196
Virginia Electric and Power Company | U.S. Treasury securities and agency debentures	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	209		231
Total Unrealized Gains	2	[1]	4	[1]
Total Unrealized Losses	-2	[1]	-1	[1]
Fair Value	209		234
Virginia Electric and Power Company | State and municipal	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	157		106
Total Unrealized Gains	6	[1]	11	[1]
Total Unrealized Losses	-3	[1]	0	[1]
Fair Value	160		117
Virginia Electric and Power Company | Other	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost, Marketable Securities	'		1
Total Unrealized Gains	'		0	[1]
Total Unrealized Losses	'		0	[1]
Fair Value	'		$1
[1]	Included in AOCI and the decommissioning trust regulatory liability.
[2]	The fair value of securities in an unrealized loss position was $487 million and $195 million at September 30, 2013 and December 31, 2012, respectively.
[3]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[4]	Includes pending sales of securities of $6 million and pending purchases of securities of $6 million at September 30, 2013 and December 31, 2012, respectively.
[5]	The fair value of securities in an unrealized loss position was $247 million and $104 million at September 30, 2013 and December 31, 2012, respectively.
[6]	Virginia Power’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[7]	Includes pending sales of securities of $4 million and $6 million at September 30, 2013 and December 31, 2012, respectively.

Investments_Fair_Value_of_our_

Investments (Fair Value of our Marketable Debt Securities by Contractual Maturity) (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Schedule of Held-to-maturity Securities [Line Items]	'
Due in one year or less	$138
Due after one year through five years	341
Due after five years through ten years	358
Due after ten years	401
Total	1,238
Virginia Electric and Power Company	'
Schedule of Held-to-maturity Securities [Line Items]	'
Due in one year or less	30
Due after one year through five years	158
Due after five years through ten years	199
Due after ten years	179
Total	$566

Investments_Selected_Informati

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Available-for-sale securities:	'		'		'		'
Proceeds from sales	$398		$276		$1,260		$1,040
Realized gains	29	[1]	15	[1]	121	[1]	71	[1]
Realized losses	13	[1]	6	[1]	29	[1]	25	[1]
Virginia Electric and Power Company	'		'		'		'
Available-for-sale securities:	'		'		'		'
Proceeds from sales	140		128		464		481
Realized gains	8	[1]	6	[1]	34	[1]	27	[1]
Realized losses	$5	[1]	$2	[1]	$13	[1]	$9	[1]
[1]	Includes realized gains and losses recorded to the decommissioning trust regulatory liability.

Regulatory_Assets_and_Liabilit2

Regulatory Assets and Liabilities (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Regulatory Assets and Liablities [Line Items]	'		'
Deferred rate adjustment clause costs	$72	[1]	$55	[1]
Derivatives	18	[2]	0	[2]
Plant retirement	6	[3]	25	[3]
Unrecovered gas cost	21	[4]	59	[4]
Other	67		64
Regulatory assets current	184	[5]	203	[5]
Unrecognized pension and other postretirement benefit costs	934	[6]	1,210	[6]
Deferred rate adjustment clause costs	257	[1]	173	[1]
Income taxes recoverable through future rates	164	[7]	140	[7]
Derivatives	34	[2]	105	[2]
Other	89		89
Regulatory assets-non-current	1,478		1,717	[8]
Total regulatory assets	1,662		1,920
PIPP	143	[9]	100	[9]
Other	45		36
Regulatory liabilities current	188	[10]	136	[10]
Provision for future cost of removal and AROs	1,031	[11]	985	[11]
Decommissioning trust	617	[12]	501	[12]
Other	70		28
Regulatory liabilities-non-current	1,718		1,514	[8]
Total regulatory liabilities	1,906		1,650
Virginia Electric and Power Company	'		'
Regulatory Assets and Liablities [Line Items]	'		'
Deferred rate adjustment clause costs	72	[1]	51	[1]
Derivatives	18	[2]	0	[2]
Plant retirement	6	[3]	25	[3]
Other	50		43
Regulatory assets current	146	[5]	119	[5]
Deferred rate adjustment clause costs	204	[1]	127	[1]
Income taxes recoverable through future rates	132	[7]	110	[7]
Derivatives	34	[2]	105	[2]
Other	50		54
Regulatory assets-non-current	420		396	[13]
Total regulatory assets	566		515
Other	37		32
Regulatory liabilities current	37	[10]	32	[10]
Provision for future cost of removal	799	[11]	763	[11]
Decommissioning trust	617	[12]	501	[12]
Other	55		21
Regulatory liabilities-non-current	1,471		1,285	[13]
Total regulatory liabilities	$1,508		$1,317
[1]	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 12 for more information.
[2]	For jurisdictions subject to cost-based rate regulation, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they are expected to be recovered from or refunded to customers.
[3]	Reflects costs anticipated to be recovered in base rates for certain coal units expected to be retired.
[4]	Reflects unrecovered gas costs at Dominion's regulated gas operations, which are recovered through annual filings with the applicable regulatory authority.
[5]	Current regulatory assets are presented in other current assets in Dominion's and Virginia Power's Consolidated Balance Sheets.
[6]	Represents unrecognized pension and other postretirement employee benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion's rate-regulated subsidiaries.
[7]	Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes.
[8]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[9]	Under PIPP, eligible customers can receive energy assistance based on their ability to pay. The difference between the customer's total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions.
[10]	Current regulatory liabilities are presented in other current liabilities in Dominion's and Virginia Power's Consolidated Balance Sheets.
[11]	Rates charged to customers by the Companies' regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.
[12]	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power's utility nuclear generation stations, in excess of the related AROs.
[13]	Virginia Power’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.

Regulatory_Assets_and_Liabilit3

Regulatory Assets and Liabilities (Narrative) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Entity Information [Line Items]	'
Regulatory assets past expenditures not earning return	$102
Period expenditures not earning return are to be recovered	'2 years
Virginia Electric and Power Company	'
Entity Information [Line Items]	'
Regulatory assets past expenditures not earning return	$65

Regulatory_Matters_Narrative_D

Regulatory Matters (Narrative) (Details) (USD $)

1 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

Sep. 30, 2013

31-May-13

Sep. 30, 2013

Sep. 30, 2013

31-May-12

Mar. 31, 2010

Jul. 31, 2008

Apr. 30, 2008

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Oct. 31, 2013

Sep. 30, 2013

Aug. 31, 2013

Jul. 31, 2013

Mar. 31, 2013

Sep. 30, 2013

Sep. 30, 2013

Nov. 05, 2013

Oct. 31, 2013

Sep. 30, 2013

Sep. 30, 2013

Aug. 31, 2013

Aug. 31, 2013

Jul. 31, 2008

Jul. 31, 2008

MMBTU

bbl

Minimum

Maximum

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

customer

mi

Project

Project

Project

Scenario, Forecast

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

1.5% Incentive Rate For Projects

1.25% Incentive Rate For Projects

MW

motion

Part

MW

Bremo Power Station

Subsequent Event

Subsequent Event

Other Current Liabilities

Noncurrent Regulatory Liability

Rider C1A

Rider C2A

Project

Project

DSM_Program

notice

DSM_Program

Regulatory Matters [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

ROE

'

'

'

'

'

'

'

11.40%

'

'

'

'

'

'

'

'

10.90%

'

'

'

'

'

'

'

'

'

Number of electric transmission projects

'

'

'

'

'

'

11

'

'

11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

7

Incentive for 4 electric transmission enhancement projects

'

'

'

'

'

'

1.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive for 7 electric transmission enhancement projects

'

'

'

'

'

'

'

'

1.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of electric transmission projects cancelled

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated cost of project abandonment

'

'

'

'

'

'

'

'

'

$7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of transmission projects approved

'

'

'

'

'

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated cost for electric transmission projects

'

'

'

'

'

'

'

'

'

'

852,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Costs claimed to be unjust and excluded from transmission formula rate

'

'

'

'

'

223,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Potential settlement required annual payment for 10 Years

'

'

'

'

'

'

'

'

250,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settlement payment duration

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earned ROE

'

'

'

'

'

'

'

'

'

'

'

'

10.30%

'

'

10.11%

'

'

'

'

'

'

'

'

'

'

Proposed base rate credit

'

'

'

'

'

'

'

'

'

'

'

9,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis points below authorized ROE

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

Requested revenue requirement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101,000,000

'

'

'

1,000,000

35,000,000

'

'

Combined spending cap inclusive of lost revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

114,000,000

'

'

'

'

'

'

'

'

'

'

'

'

New DSM programs

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

Currently approved fuel factor rate (cents per kWh)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.02942

'

'

'

'

'

'

Requested fuel factor rate (cents per kWh)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.02572

'

'

'

'

'

'

Reduction in anticipated fuel recoveries

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

140,000,000

'

'

'

'

'

'

Fuel recoveries

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

47,000,000

'

'

'

'

Capacity (MW)

'

'

'

'

'

'

'

'

'

'

'

'

227

'

'

'

227

'

'

'

'

'

'

'

'

'

Proposed conversion expected cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

53,000,000

'

'

'

'

'

'

'

'

Respondents who filed motions for reconsideration

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

Number of Filed Notices to Appeal Final Order

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

Requested ROE

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12.50%

'

'

'

'

'

'

'

Basis points enhancement to Roe

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

Number of parts of amendment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

Cost of project

$42,000,000

$147,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capacity of project

185,000

27,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Customers that have entered into binding agreement for full project capacity

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period for full project capacity

'

'

'8 years

'13 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Length of pipeline

'

58

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Variable_Interest_Entities_Nar

Variable Interest Entities (Narrative) (Details) (USD $)	9 Months Ended		1 Months Ended	110 Months Ended		3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Aug. 31, 2013	Aug. 31, 2013	Oct. 31, 2011	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2013
			Juniper	Juniper	Juniper	Virginia Electric and Power Company	Virginia Electric and Power Company	Virginia Electric and Power Company	Virginia Electric and Power Company	Virginia Electric and Power Company	Virginia Electric and Power Company
								MW		Minimum	Maximum
								generator
Variable Interest Entities [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Long term capacity contract non utility generators (generators)	'	'	'	'	'	'	'	4	'	'	'
Aggregate generation capacity from long-term power and capacity contracts (MW)	'	'	'	'	'	'	'	870	'	'	'
Contracts expiry date start range	'	'	'	'	'	'	'	'	'	'2015	'2021
Remaining purchase commitments	'	'	'	'	'	'	'	$920	'	'	'
Payment for electric capacity	'	'	'	'	'	53	52	161	160	'	'
Payment for electric energy	'	'	'	'	'	29	27	74	62	'	'
Shared services purchased	'	'	'	'	'	88	86	248	238	'	'
Annual lease payments	'	'	'	53	'	'	'	'	'	'	'
Fair value of property plant and equipment	'	'	'	'	957	'	'	'	'	'	'
Fair value of debt	'	'	'	'	896	'	'	'	'	'	'
Fair value of noncontrolling interest	'	'	'	'	61	'	'	'	'	'	'
Acquisition of Juniper noncontrolling interest	$923	$0	$923	'	'	'	'	'	'	'	'

Significant_Financing_Transact2

Significant Financing Transactions - (Narrative) (Details) (USD $)

1 Months Ended

9 Months Ended

1 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

1 Months Ended

Jan. 31, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2013

Jan. 31, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Jan. 31, 2013

Jan. 31, 2013

Mar. 31, 2013

31-May-13

Mar. 31, 2013

Mar. 31, 2013

Mar. 31, 2013

Sep. 30, 2013

Sep. 30, 2013

Jun. 30, 2013

Aug. 31, 2013

Oct. 22, 2013

Jul. 31, 2016

Apr. 30, 2016

Jul. 31, 2016

Apr. 30, 2016

Sep. 30, 2013

Dominion Iroquois Inc

Class A

Class A

Class B

Class B

7.83 percent Debentures due 12/01/2027

Convertible Debt

Virginia Electric and Power Company

Virginia Electric and Power Company

1.2% Senior Notes That Mature In 2018

4% Senior Notes That Mature In 2043

2.75% Senior Notes that mature in 2023

Secured Senior Note, 7.33%, due 2020

2.5% Bonds That Mature In 2031

2.5% Bonds that Mature in 2022

2.5% Bonds that Mature in 2030

Tax Exempt Debt

Tax Exempt Debt

Variable Rate MDFA Solid Waste Disposal Revenue Bonds, Due2041

4.65% Senior Notes due in 2043

Unsecured Senior Notes

Minimum

Minimum

Maximum

Maximum

Common Stock

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Kincaid

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Brayton Point

Virginia Electric and Power Company

Virginia Electric and Power Company

Senior Notes

Senior Notes

Scenario, Forecast

Scenario, Forecast

Scenario, Forecast

Scenario, Forecast

Subsequent Event

Debt Instrument [Line Items]

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Credit facility

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$120,000,000

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Variable rate tax-exempt financings

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'

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'

'

'

'

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'

'

'

'

'

'

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'

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119,000,000

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Senior notes

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'

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250,000,000

500,000,000

500,000,000

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'

'

'

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'

'

'

'

'

'

RSN Annual Interest Rate

'

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'

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7.83%

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1.20%

4.00%

2.75%

7.33%

2.50%

2.50%

2.50%

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'

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4.65%

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'

'

'

'

'

Amount of outstanding principal amount redeemed

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'

'

'

'

'

'

'

'

'

'

'

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145,000,000

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'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt

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1,214,000,000

1,037,000,000

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462,000,000

10,000,000

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185,000,000

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Outstanding principal amount

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'

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'

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'

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257,000,000

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'

'

'

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Amount delivered to irrevocable trust

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'

'

'

'

'

'

'

'

'

'

'

'

'

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284,000,000

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'

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Virginia Solid Waste and Sewage Disposal Revenue Bonds

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'

'

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'

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'

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50,000,000

10,000,000

30,000,000

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75,000,000

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'

'

'

'

'

'

Total Long-term Debt

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'

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'

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'

'

'

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'

'

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'

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585,000,000

1,200,000,000

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'

'

'

'

Contingent convertible senior notes

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'

'

'

'

'

'

'

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44,000,000

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conversion rate, shares of common stock per $1,000 principal amount of senior notes (in shares)

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'

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29.7664

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'

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'

'

Principal amount of senior notes

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$1,000

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Conversion rate, shares of common stock per $1,000 principal amount of senior notes, conversion price

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'

'

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$33.59

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'

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Issuance of additional shares

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'

'

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600,000

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Average Trading Price Principal Amount Of Senior Notes (percentage)

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120.00%

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'

'

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'

Minimum Consecutive Trading Days

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'20 days

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'

Maximum Consecutive Trading Days

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'30 days

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Debt conversion converted instrument amount

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38,000,000

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Unsecured junior subordinated debentures

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258,000,000

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'

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'

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'

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Number of units redeemed

250,000

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Dominion Resources Capital Trust I capital securities

250,000,000

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'

Interest rate for the Dominion Resources Capital Trust I securities

7.83%

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Redemption price of the capital security

$1,019.58

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'

Amount of Equity Units issued

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$550,000,000

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$550,000,000

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Compounded contract adjustment payment rate

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6.13%

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6.00%

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'

Interest in RSN issued by Dominion

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5.00%

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Purchase price to be paid under stock purchase contracts (dollars per share)

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$50

Shares to be issued

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8,400,000

8,400,000

9,900,000

9,900,000

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Total shares reserved for issuance

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22,500,000

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'

General partnership interest (percentage)

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24.72%

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'

'

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'

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'

'

'

'

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'

'

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'

'

'

Significant_Financing_Transact3

Significant Financing Transactions - (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Details) (USD $)	Sep. 30, 2013
Line of Credit Facility [Line Items]	'
Facility Limit	$3,500,000,000
Outstanding Commercial Paper	2,145,000,000
Outstanding Letters of Credit	18,000,000
Facility Capacity Available	1,337,000,000
Virginia Electric and Power Company	'
Line of Credit Facility [Line Items]	'
Facility Limit	1,250,000,000
Outstanding Commercial Paper	485,000,000
Outstanding Letters of Credit	1,000,000
Facility Capacity Available	764,000,000
Credit Facility 1.5 Billion	'
Line of Credit Facility [Line Items]	'
Facility Limit	3,000,000,000	[1]
Outstanding Commercial Paper	2,145,000,000	[1]
Outstanding Letters of Credit	0	[1]
Facility Capacity Available	855,000,000	[1]
Credit Facility, to support letters of credit	1,500,000,000
Credit Facility 1.5 Billion | Virginia Electric and Power Company	'
Line of Credit Facility [Line Items]	'
Facility Limit	1,000,000,000	[2]
Outstanding Commercial Paper	485,000,000	[2]
Outstanding Letters of Credit	0	[2]
Facility Capacity Available	515,000,000	[2]
Credit Facility, to support letters of credit	1,500,000,000
Credit Facility 500 Million	'
Line of Credit Facility [Line Items]	'
Facility Limit	500,000,000	[3]
Outstanding Commercial Paper	0	[3]
Outstanding Letters of Credit	18,000,000	[3]
Facility Capacity Available	482,000,000	[3]
Amount of committed capacity extended	400,000,000
Amount of remaining committed capacity extended	100,000,000
Credit Facility 500 Million | Virginia Electric and Power Company	'
Line of Credit Facility [Line Items]	'
Facility Limit	250,000,000	[4]
Outstanding Commercial Paper	0	[4]
Outstanding Letters of Credit	1,000,000	[4]
Facility Capacity Available	$249,000,000	[4]
[1]	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion of letters of credit.
[2]	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (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.
[3]	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
[4]	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.

Significant_Financing_Transact4

Significant Financing Transactions (Schedule of Equity Units) (Details) (USD $)	0 Months Ended
Share data in Millions, unless otherwise specified	Jun. 07, 2013	Jun. 07, 2013	Sep. 30, 2013	Jun. 07, 2013	Sep. 30, 2013	Jun. 07, 2013
	Class A	Class B	Remarketable Subordinated Notes	Remarketable Subordinated Notes	Remarketable Subordinated Notes	Remarketable Subordinated Notes
			Class A	Class A	Class B	Class B
Capital Unit [Line Items]	'	'	'	'	'	'
Units Issued	11	11	'	'	'	'
Total Net Proceeds	$533,500,000	$533,500,000	'	'	'	'
Total Long-term Debt	'	'	'	550,000,000	'	550,000,000
RSN Annual Interest Rate	'	'	1.07%	'	1.18%	'
Stock Purchase Contract Annual Rate	5.06%	4.82%	'	'	'	'
Stock Purchase Contract Liability	$76,700,000	$79,300,000	'	'	'	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Narrative) (Details) (USD $)

1 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

Feb. 28, 2013

Sep. 30, 2011

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Jul. 31, 2011

Sep. 30, 2013

Apr. 25, 2013

Sep. 30, 2013

T

Party

Site

T

Third Party and Equity Method Investee

Third Party and Equity Method Investee

Sep-13

Minimum

Maximum

CAA

CAA

CAA

Virginia Electric and Power Company

Through 2019

Nuclear Obligations

Group

Site

MW

State

Investments in and Advances to Affiliates [Line Items]

'

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'

'

'

'

'

'

'

'

'

'

'

Number of states under EPA replacement rule

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28

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'

'

Emissions of fossil fuel fired electric generating units (MW)

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25

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'

'

Number of groups of affected states

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'

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2

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'

'

Amount of civil penalty

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'

'

'

$68,000,000

'

'

'

'

'

$13,000,000

$3,000,000

'

Amount to fund environmental mitigation projects

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

Number of parties issued UAO

'

22

'

'

'

'

'

'

'

'

'

'

'

Daily civil penalties for non compliance

'

'

37,500

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'

'

'

'

'

'

'

'

'

Number of former manufactured gas plant sites

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17

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'

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'

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'

3

Percentage reduction in CO2 Emissions

10.00%

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'

'

'

'

'

'

'

'

'

'

CO2 emissions cap

91,000,000

'

'

165,000,000

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'

'

'

'

'

'

'

'

Percent further emmision reduction goals in participating state power plant CO2 emissions (percentage)

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2.50%

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'

'

'

'

'

'

'

'

Liability protection per nuclear incident

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'

13,600,000,000

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'

'

'

'

Inflationary provision adjustment period

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'5 years

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'

'

'

'

'

'

'

'

'

Coverage from commercial insurance pools

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'

375,000,000

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'

'

'

'

'

'

'

'

'

Amounts assessed for each licensed reactor

'

'

127,000,000

'

'

'

'

'

'

'

'

'

'

Amount assessed per year per reactor

'

'

19,000,000

'

'

'

'

'

'

'

'

'

'

Minimum requirement for nuclear power plant licenses per reactor site

'

'

1,060,000,000

'

'

'

'

'

'

'

'

'

'

Maximum retrospective premium assessment for nuclear power plant licensees

'

'

71,000,000

'

'

'

'

'

'

'

'

'

39,000,000

Maximum retrospective premium assessment for replacement power costs

'

'

19,000,000

'

'

'

'

'

'

'

'

'

9,000,000

Exposure under guarantees

'

'

4,423,000,000

'

38,000,000

90,000,000

'

'

'

'

'

'

'

Annual future contributions

'

'

'

'

'

'

'

4,000,000

19,000,000

'

'

'

'

Purchased surety bonds

'

'

146,000,000

'

'

'

'

'

'

'

'

'

59,000,000

Authorized issuance of standby letters of credit

'

'

$18,000,000

'

'

'

'

'

'

'

'

'

$1,000,000

Commitments_and_Contingencies_2

Commitments and Contingencies (Schedule of Nuclear Insurance Coverage) (Details) (USD $)	Sep. 30, 2013
Millstone	'
Loss Contingencies [Line Items]	'
Coverage	$1,700,000,000
Kewaunee	'
Loss Contingencies [Line Items]	'
Coverage	1,060,000,000
Surry And North Anna	'
Loss Contingencies [Line Items]	'
Blanket property limit	450,000,000
Virginia Electric and Power Company | Surry	'
Loss Contingencies [Line Items]	'
Coverage	1,700,000,000	[1]
Virginia Electric and Power Company | North Anna	'
Loss Contingencies [Line Items]	'
Coverage	$1,700,000,000	[1]
[1]	Surry and North Anna share a blanket property limit of $450 million

Commitments_and_Contingencies_3

Commitments and Contingencies (Subsidiary Guarantees) (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Commitments and Contingencies [Line Items]	'
Stated Limit	$4,423
Value	517	[1]
Subsidiary Debt	'
Commitments and Contingencies [Line Items]	'
Stated Limit	27	[2]
Value	27	[1],[2]
Commodity Transactions	'
Commitments and Contingencies [Line Items]	'
Stated Limit	3,181	[3]
Value	343	[1],[3]
Nuclear Obligations	'
Commitments and Contingencies [Line Items]	'
Stated Limit	232	[4]
Value	55	[1],[4]
Cove Point	'
Commitments and Contingencies [Line Items]	'
Stated Limit	335	[5]
Value	0	[1],[5]
Other	'
Commitments and Contingencies [Line Items]	'
Stated Limit	648	[6]
Value	92	[1],[6]
Millstone | Nuclear Obligations	'
Commitments and Contingencies [Line Items]	'
Stated Limit	150
Kewaunee | Nuclear Obligations	'
Commitments and Contingencies [Line Items]	'
Stated Limit	$60
[1]	Represents the estimated portion of the guarantee's stated limit that is utilized as of September 30, 2013 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]	Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, 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. The agreement for Kewaunee also provides for funds through the completion of decommissioning.
[5]	Guarantees related to Cove Point, including agreements to support terminal service and transportation agreements as well as an engineering, procurement and construction contract for new liquefaction facilities. Includes certain guarantees that do not have stated limits.
[6]	Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries' obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower.

Credit_Risk_Narrative_Details

Credit Risk (Narrative) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
	Counterparty
Concentration Risk and Guarantor Obligations [Line Items]	'	'
Gross credit exposure	$205	'
Number of counterparties	0	'
Additional collateral to be posted if the credit related contingent features were triggered	48	110
Collateral posted	3	4
Fair value of all derivative instruments not fully collateralized	$86	$163
Investment Grade | Investment grade counterparties	'	'
Concentration Risk and Guarantor Obligations [Line Items]	'	'
Concentration risk, percentage (percentage)	63.00%	'
Investment Grade | Counterparty, A	'	'
Concentration Risk and Guarantor Obligations [Line Items]	'	'
Concentration risk, percentage (percentage)	10.00%	'

Related_Party_Transactions_Det

Related Party Transactions (Details) (Virginia Electric and Power Company, USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Related Party Transaction [Line Items]	'	'	'	'	'
Commodity purchases from affiliates	$138,000,000	$129,000,000	$328,000,000	$285,000,000	'
Services provided by affiliates	109,000,000	107,000,000	311,000,000	298,000,000	'
Outstanding borrowings, net of repayments, under money pool for non-regulated subsidiaries	0	'	0	'	192,000,000
Principal Owner	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Short term demand note	'	'	'	'	$243,000,000

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)	9 Months Ended
	Sep. 30, 2013
Defined Benefit Plan Disclosure [Line Items]	'
Reduction in pension benefit obligation from remeasurement and curtailments	$354,000,000
Reduction in accumulated postretirement benefit obligation	78,000,000
Reduction in net periodic benefit cost for 2013	36,000,000
Contributions to defined benefit pension plans and OPEB plans	0
Expected contribution to voluntary employees' beneficiary association	$12,000,000
Pension Benefits	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.80%
Other Postretirement Benefits	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.70%

Employee_Benefit_Plans_Net_Per

Employee Benefit Plans (Net Periodic Benefit Cost) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Pension Benefits	'		'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'		'
Service cost	$31		$29		$100		$87
Interest cost	69		67		202		201
Expected return on plan assets	-116		-108		-345		-323
Amortization of prior service credit	0		0		2		2
Amortization of net loss	37		33		127		99
Settlements and curtailments	0	[1]	0	[1]	-2	[1],[2]	0	[1],[2]
Net periodic benefit cost	21		21		84		66
Other Postretirement Benefits	'		'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'		'
Service cost	10		11		34		33
Interest cost	19		20		56		60
Expected return on plan assets	-24		-19		-68		-60
Amortization of prior service credit	-3		-4		-9		-10
Amortization of net loss	2		2		6		5
Settlements and curtailments	0	[1]	-4	[1]	-15	[1],[2]	-4	[1],[2]
Net periodic benefit cost	$4		$6		$4		$24
[1]	2012 amount relates primarily to the sale of Salem Harbor.
[2]	2013 amount relates primarily to the decommissioning of Kewaunee.

Goodwill_Details

Goodwill (Details) (USD $)	9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Goodwill [Roll Forward]	'		'
Goodwill, Balance at beginning of period	$3,130	[1],[2]	$3,141	[1]
Asset disposition adjustment	-43		-11
Goodwill, Balance at end of period	3,087	[1]	3,130	[1],[2]
Dominion Generation	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Balance at beginning of period	1,338	[1]	1,338	[1]
Asset disposition adjustment	-16	[3]	0
Goodwill, Balance at end of period	1,322	[1]	1,338	[1]
Dominion Energy	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Balance at beginning of period	701	[1]	712	[1]
Asset disposition adjustment	-24	[4]	-11
Goodwill, Balance at end of period	677	[1]	701	[1]
DVP	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Balance at beginning of period	1,091	[1]	1,091	[1]
Asset disposition adjustment	-3	[3]	0
Goodwill, Balance at end of period	1,088	[1]	1,091	[1]
Corporate and Other	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Balance at beginning of period	0	[1]	0	[1]
Asset disposition adjustment	0		0
Goodwill, Balance at end of period	$0	[1]	$0	[1]
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	Dominion’s Consolidated Balance Sheet at December 31, 2012 has been derived from the audited Consolidated Financial Statements at that date.
[3]	See Note 3 in this report for a discussion of Dominion's dispositions and related goodwill write-offs.
[4]	Related to assets sold or contributed to Blue Racer.

Operating_Segments_Narrative_D

Operating Segments (Narrative) (Details) (USD $)	3 Months Ended				9 Months Ended				12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012		Dec. 31, 2012
Segment Reporting Information [Line Items]	'		'		'		'		'
Loss from discontinued operations	($23)	[1]	($52)	[1],[2]	($92)	[1]	($94)	[1],[3]	'
Write off of goodwill	'		'		43		'		11
Impairment of merchant generation assets	'		'		48		444		'
Severance pay and other	'		'		28		'		'
Severance after tax	'		'		17		'		'
Income tax expense	305		143	[2]	709		578	[3]	'
Corporate and Other	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
After tax net expenses	'		'		148		413		'
Write off of goodwill	'		'		0		'		0
All segments	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
After tax net expenses	'		'		144		422		'
Dominion Generation	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Write off of goodwill	'		'		16	[4]	'		0
Net gain on investments	'		'		66		'		'
Net gain on invesments, after tax	'		'		40		'		'
Dominion Generation | Elwood	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Net gain on the sale of Brayton Point, Kincaid and equity method investment in Elwood	'		'		35		'		'
After tax gain on sale of equity method investment	'		'		25		'		'
Dominion Energy	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Write off of goodwill	'		'		24	[5]	'		11
Net loss	'		'		130		'		'
After tax net loss	'		'		74		'		'
Impairment of merchant generation assets	'		'		55		'		'
Impairment charge for certain natural gas infrastructure facilities, net of tax	'		'		33		'		'
Loss related to restructuring of producer services	'		'		75		'		'
Restructuring after tax	'		'		41		'		'
DVP	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Write off of goodwill	'		'		3	[4]	'		0
Restoration costs	'		'		'		69		'
Restortation costs, net of tax	'		'		'		42		'
Brayton Point and Kincaid | Dominion Generation	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Net loss from discontinued operations, before income tax	'		'		135		98		'
Loss from discontinued operations	'		'		92		72		'
Debt extinquishment and other costs	'		'		64		'		'
Debt extinguishment and other costs, after tax	'		'		38		'		'
Impairment of long-lived assets to be disposed of	'		'		48		'		'
Impairment of long lived assets to be disposed of, net of tax	'		'		28		'		'
Benefit from discontinued operations	'		'		17		'		'
Benefit from discontinued operations, net of tax	'		'		18		'		'
Net loss	'		'		6		'		'
After tax net loss	'		'		8		'		'
Income tax expense	'		'		'		25		'
Kewaunee | Dominion Generation	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Net loss from discontinued operations, before income tax	'		'		'		458		'
Loss from discontinued operations	'		'		'		297		'
State Line and Salem Harbor | Dominion Generation	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Net loss from discontinued operations, before income tax	'		'		'		49		'
Loss from discontinued operations	'		'		'		22		'
Virginia Electric and Power Company	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Income tax expense	218		259		534		513		'
Virginia Electric and Power Company | Corporate and Other	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
After tax net expenses	'		'		5		41		'
Virginia Electric and Power Company | DVP	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Restoration costs	'		'		'		69		'
Restortation costs, net of tax	'		'		'		$42		'
[1]	Includes income tax expense of $6 million for the three months ended September 30, 2013 and income tax benefit of $17 million, $43 million and $53 million for the three months ended September 30, 2012 and the nine months ended September 30, 2013 and 2012, respectively.
[2]	Recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
[3]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[4]	See Note 3 in this report for a discussion of Dominion's dispositions and related goodwill write-offs.
[5]	Related to assets sold or contributed to Blue Racer.

Operating_Segments_Schedule_of

Operating Segments (Schedule of Segment Reporting Information, by Segment) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	$3,432		$3,332	[1]	$9,935		$9,734	[2]
Total operating revenue	3,432		3,332		9,935		9,734
Loss from discontinued operations	-23		-52	[1]	-92		-94	[2]
Net income attributable to Dominion	569		209	[1],[2]	1,266		961	[2]
Intersegment Revenue	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	0		0		0		0
DVP	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	829		836		2,508		2,573
Total operating revenue	837		842		2,564		2,654
Loss from discontinued operations	0		0		0		0
Net income attributable to Dominion	124		119		398		428
DVP | Intersegment Revenue	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	8		6		56		81
Dominion Generation	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	1,882	[3]	1,824	[3]	5,034	[3]	4,960	[3]
Total operating revenue	1,992	[3]	1,934	[3]	5,271	[3]	5,235	[3]
Loss from discontinued operations	0	[3]	0	[3]	0	[3]	0	[3]
Net income attributable to Dominion	338	[3]	363	[3]	730	[3]	762	[3]
Dominion Generation | Intersegment Revenue	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	110	[3]	110	[3]	237	[3]	275	[3]
Dominion Energy	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	361		291		1,326		1,278
Total operating revenue	642		572		2,147		1,979
Loss from discontinued operations	0		0		0		0
Net income attributable to Dominion	169		104		472		362
Dominion Energy | Intersegment Revenue	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	281		281		821		701
Corporate and Other	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	-10	[3]	37	[3]	54	[3]	109	[3]
Total operating revenue	148	[3]	201	[3]	518	[3]	568	[3]
Loss from discontinued operations	-23	[3]	-52	[3]	-92	[3]	-94	[3]
Net income attributable to Dominion	-62	[3]	-377	[3]	-334	[3]	-591	[3]
Corporate and Other | Intersegment Revenue	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	158	[3]	164	[3]	464	[3]	459	[3]
Adjustments/Eliminations	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	370		344		1,013		814
Total operating revenue	-187		-217		-565		-702
Loss from discontinued operations	0		0		0		0
Net income attributable to Dominion	0		0		0		0
Adjustments/Eliminations | Intersegment Revenue	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	-557		-561		-1,578		-1,516
Virginia Electric and Power Company	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total revenue from external customers	2,059		2,086		5,550		5,596
Total operating revenue	2,059		2,086		5,550		5,596
Net income attributable to Dominion	387		415		939		830
Virginia Electric and Power Company | DVP	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total operating revenue	470		505		1,366		1,413
Net income attributable to Dominion	123		128		355		335
Virginia Electric and Power Company | Dominion Generation	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total operating revenue	1,589		1,581		4,184		4,183
Net income attributable to Dominion	262		283		587		534
Virginia Electric and Power Company | Corporate and Other	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total operating revenue	0		0		0		0
Net income attributable to Dominion	$2		$4		($3)		($39)
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
[2]	Net of $43 million and $57 million tax for the three months ended September 30, 2013 and 2012, respectively, and net of $21 million and $(28) million tax for the nine months ended September 30, 2013 and 2012, respectively.
[3]	2012 amounts have been recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.