Dominion Energy Gas 10-K 27 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Jan. 31, 2015	Jun. 30, 2014
Document Information [Line Items]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	D
Entity Registrant Name	DOMINION RESOURCES INC /VA/
Entity Central Index Key	715957
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		588,138,107
Entity Well Known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Public Float			$41,100,000,000
Virginia Electric and Power Company
Document Information [Line Items]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	VEL - PE
Entity Registrant Name	VIRGINIA ELECTRIC & POWER CO
Entity Central Index Key	103682
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		274,723
Entity Well Known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Public Float			0
Dominion Gas Holdings, LLC
Document Information [Line Items]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Entity Registrant Name	Dominion Gas Holdings, LLC
Entity Central Index Key	1603291
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
Entity Well Known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Public Float			$0

Consolidated_Statements_of_Inc

Consolidated Statements of Income (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Operating Revenue	$12,436		$13,120		$12,835
Operating Expenses
Electric fuel and other energy-related purchases	3,400		3,885		3,645
Purchased electric capacity	361		358		387
Purchased gas	1,355		1,331		1,177
Other operations and maintenance	2,765		2,459		3,091
Depreciation, depletion and amortization	1,292		1,208		1,127
Other taxes	542		563		550
Total operating expenses	9,715		9,804		9,977
Income from operations	2,721		3,316		2,858
Other income	250		265		223
Interest and related charges	1,193		877		816
Income from continuing operations including noncontrolling interests before income taxes	1,778		2,704		2,265
Income tax expense	452		892		811
Income from continuing operations including noncontrolling interests	1,326		1,812		1,454
Income (loss) from discontinued operations	0	[1]	-92	[1]	-1,125	[1]
Net income including noncontrolling interests	1,326		1,720		329
Noncontrolling interests	16		23		27
Net income attributable to Dominion	1,310		1,697		302
Amounts attributable to Dominion:
Income from continuing operations, net of tax	1,310	[2]	1,789	[2]	1,427
Loss from discontinued operations, net of tax	0		-92		-1,125
Net income attributable to Dominion	1,310		1,697		302
Earnings Per Common Share-Basic:
Income from continuing operations (in dollars per share)	$2.25	[2]	$3.09	[2]	$2.49
Loss from discontinued operations (in dollars per share)	$0		($0.16)	[2]	($1.96)
Net income attributable to Dominion (in dollars per share)	$2.25		$2.93		$0.53
Earnings Per Common Share-Diluted:
Income from continuing operations (in dollars per share)	$2.24	[2]	$3.09	[2]	$2.49
Loss from discontinued operations (in dollars per share)	$0		($0.16)	[2]	($1.96)
Net income attributable to Dominion (in dollars per share)	$2.24		$2.93		$0.53
Dividends declared per common share	$2.40		$2.25		$2.11
Virginia Electric and Power Company
Operating Revenue	7,579	[3]	7,295	[3]	7,226	[3]
Operating Expenses
Electric fuel and other energy-related purchases	2,406	[3]	2,304	[3]	2,368	[3]
Purchased electric capacity	360		358		386
Affiliated suppliers	286		290		305
Other	1,630		1,161		1,161
Depreciation, depletion and amortization	915		853		782
Other taxes	258		249		232
Total operating expenses	5,855		5,215		5,234
Income from operations	1,724		2,080		1,992
Other income	93		86		96
Interest and related charges	411		369		385
Income from continuing operations including noncontrolling interests before income taxes	1,406		1,797		1,703
Income tax expense	548		659		653
Net income attributable to Dominion	858		1,138		1,050
Amounts attributable to Dominion:
Net income attributable to Dominion	858		1,138		1,050
Preferred dividends(2)	13	[4]	17	[4]	16	[4]
Balance available for common stock	845		1,121		1,034
Dominion Gas Holdings, LLC
Operating Revenue	1,898	[5]	1,937	[5]	1,677	[5]
Operating Expenses
Purchased gas	315	[5]	323	[5]	235	[5]
Other energy-related purchases	40		93		41
Affiliated suppliers	64		70		112
Other	274	[6]	353	[6]	223	[6]
Depreciation, depletion and amortization	197		188		176
Other taxes	157		148		140
Total operating expenses	1,047		1,175		927
Income from operations	851		762		750
Other income	22		28		37
Interest and related charges	27	[5]	28	[5]	40	[5]
Income from continuing operations including noncontrolling interests before income taxes	846		762		747
Income tax expense	334		301		288
Net income attributable to Dominion	512		461		459
Amounts attributable to Dominion:
Net income attributable to Dominion	$512		$461		$459
[1]	Includes income tax benefit of $43 million and $692 million in 2013 and 2012, respectively. For 2012, includes impairment charges of $1.6 billion related to Brayton Point and Kincaid. See Note 6 for additional information.
[2]	Amounts attributable to Dominion's common shareholders.
[3]	See Note 24 for amounts attributable to affiliates.
[4]	Includes $2 million associated with the write-off of issuance expenses related to the redemption of Virginia Power's preferred stock in 2014. See Note 18 for additional information.
[5]	See Note 24 for amounts attributable to related parties.
[6]	Includes gains on the sales of assets to related parties of $59 million, $122 million and $176 million in 2014, 2013 and 2012, respectively. See Note 9 for more information.

Consolidated_Statements_of_Inc1

Consolidated Statements of Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Discontinued operation tax expense		$43	$692
Impairment charge			1,600
Issuance expenses related to redemption of preferred stock	2
Dominion Gas Holdings, LLC | Affiliated Entity
Gain on sale of assets	$59	$122	$176

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net income including noncontrolling interests	$1,326	$1,720	$329
Net income attributable to Dominion	1,310	1,697	302
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	17	-243	-8
Changes in unrealized net gains on investment securities, net of tax	128	203	108
Changes in net unrecognized pension and other postretirement benefit costs, net of tax	-305	516	-330
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	93	77	-60
Net realized gains on investment securities, net of tax	-54	-55	-25
Net pension and other postretirement benefit costs, net of tax	33	55	48
Changes in other comprehensive income (loss) from equity method investees, net of tax	-4	0	0
Other comprehensive income (loss)	-92	553	-267
Comprehensive income including noncontrolling interests	1,234	2,273	62
Comprehensive income attributable to noncontrolling interests	16	23	27
Comprehensive income	1,218	2,250	35
Virginia Electric and Power Company
Net income attributable to Dominion	858	1,138	1,050
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	-4	6	-5
Changes in unrealized net gains on investment securities, net of tax	15	20	13
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	-3	0	2
Net realized gains on investment securities, net of tax	-6	-3	-4
Other comprehensive income (loss)	2	23	6
Comprehensive income	860	1,161	1,056
Dominion Gas Holdings, LLC
Net income attributable to Dominion	512	461	459
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	-31	39	13
Changes in net unrecognized pension and other postretirement benefit costs, net of tax	-10	26	-7
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	8	11	20
Net pension and other postretirement benefit costs, net of tax	5	6	5
Other comprehensive income (loss)	-28	82	31
Comprehensive income	$484	$543	$490

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net deferred gains (losses) on derivatives-hedging activities, tax	($20)	$161	$5
Changes in unrealized net gains (losses) on investment securities, tax	-59	-136	-68
Changes in net unrecognized pension and other postretirement benefit costs, tax	189	-341	209
Net derivative (gains) losses-hedging activities, tax	-59	-53	34
Net realized (gains) losses on investment securities, tax	33	35	16
Net pension and other postretirement benefit costs, tax	-24	-39	-32
Changes in other comprehensive income (loss) from equity method investees, tax	3	0	0
Virginia Electric and Power Company
Net deferred gains (losses) on derivatives-hedging activities, tax	2	-3	3
Changes in unrealized net gains (losses) on investment securities, tax	-9	-13	-7
Net derivative (gains) losses-hedging activities, tax	2	0	-2
Net realized (gains) losses on investment securities, tax	4	2	2
Dominion Gas Holdings, LLC
Net deferred gains (losses) on derivatives-hedging activities, tax	19	-27	-10
Changes in net unrecognized pension and other postretirement benefit costs, tax	6	-18	5
Net derivative (gains) losses-hedging activities, tax	-5	-5	-13
Net pension and other postretirement benefit costs, tax	($3)	($4)	($4)

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets
Cash and cash equivalents	$318		$316
Customer receivables	1,514		1,695
Other receivables	119		141
Inventories:
Materials and supplies	923		689
Fossil fuel	413		393
Gas stored	74		94
Derivative assets	536		687
Margin deposit assets	287		620
Prepayments	167		192
Deferred income taxes	800		778
Regulatory assets	347		217
Other	117		118
Total current assets	5,615		5,940
Investments
Nuclear decommissioning trust funds	4,196		3,903
Investment in equity method affiliates	1,081		916
Other	284		283
Total investments	5,561		5,102
Property, Plant and Equipment
Property, plant and equipment	51,406		46,969
Accumulated depreciation, depletion and amortization	-15,136		-14,341
Total property, plant and equipment, net	36,270		32,628
Deferred Charges and Other Assets
Goodwill	3,044	[1]	3,086	[1]
Pension and other postretirement benefit assets	956		942
Intangible assets, net	570		560
Regulatory assets	1,642		1,228
Other	669		610
Total deferred charges and other assets	6,881		6,426
Total assets	54,327		50,096
Current Liabilities
Securities due within one year	1,375		1,519
Short-term debt	2,775		1,927
Accounts payable	952		1,168
Accrued interest, payroll and taxes	566		609
Derivative liabilities	591		828
Regulatory liabilities	170	[2]	128	[2]
Other	939		943
Total current liabilities	7,198		6,994
Long-Term Debt
Long-term debt	18,348		16,877
Junior subordinated notes	1,374		1,373
Remarketable subordinated notes	2,083		1,080
Total long-term debt	21,805		19,330
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits	7,444		7,114
Asset retirement obligations	1,633		1,484
Pension and other postretirement benefit liabilities	1,296		481
Regulatory liabilities	1,991		2,001
Other	1,003		793
Total deferred credits and other liabilities	13,367		11,873
Total liabilities	42,370		38,197
Commitments and Contingencies (see Note 22)
Subsidiary Preferred Stock Not Subject To Mandatory Redemption	0		257
Equity
Common stock-no par	5,876	[3]	5,783	[3]
Retained earnings	6,095		6,183
Accumulated other comprehensive loss	-416		-324
Total common shareholders' equity	11,555		11,642
Noncontrolling interest	402		0
Total equity	11,957		11,642
Total liabilities and equity	54,327		50,096
Virginia Electric and Power Company
Current Assets
Cash and cash equivalents	15		16
Customer receivables	986		946
Other receivables	65		78
Inventories:
Materials and supplies	455		418
Fossil fuel	398		390
Prepayments	252		32
Deferred income taxes	6		87
Regulatory assets	298		128
Other	76	[4]	68	[4]
Total current assets	2,551		2,163
Investments
Nuclear decommissioning trust funds	1,930		1,765
Other	4		12
Total investments	1,934		1,777
Property, Plant and Equipment
Property, plant and equipment	35,180		32,848
Accumulated depreciation, depletion and amortization	-11,080		-10,580
Total property, plant and equipment, net	24,100		22,268
Deferred Charges and Other Assets
Intangible assets, net	205		193
Regulatory assets	439		417
Other	280	[4]	143	[4]
Total deferred charges and other assets	924		753
Total assets	29,509		26,961
Current Liabilities
Securities due within one year	211		58
Short-term debt	1,361		842
Accounts payable	458		479
Payables to affiliates	92		69
Affiliated current borrowings	427		97
Accrued interest, payroll and taxes	199		218
Derivative liabilities	60		12
Customer deposits	107		95
Regulatory liabilities	90		41
Other	271		306
Total current liabilities	3,276		2,217
Long-Term Debt
Total long-term debt	8,726		7,974
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits	4,415		4,137
Asset retirement obligations	848		689
Pension and other postretirement benefit liabilities	219	[4]	147	[4]
Regulatory liabilities	1,683		1,597
Other	287		145
Total deferred credits and other liabilities	7,452		6,715
Total liabilities	19,454		16,906
Commitments and Contingencies (see Note 22)
Subsidiary Preferred Stock Not Subject To Mandatory Redemption	0		257
Equity
Common stock-no par	5,738	[5]	5,738	[5]
Other paid-in capital	1,113		1,113
Retained earnings	3,154		2,899
Accumulated other comprehensive loss	50		48
Total common shareholders' equity	10,055		9,798
Total equity	10,055		9,798
Total liabilities and equity	29,509		26,961
Dominion Gas Holdings, LLC
Current Assets
Cash and cash equivalents	9		8
Customer receivables	322	[6]	311	[6]
Other receivables	19		2
Affiliated receivables	12		41
Inventories:
Materials and supplies	53		56
Gas stored	12		7
Prepayments	166		67
Deferred income taxes	96		89
Regulatory assets	38		79
Other	83	[6]	141	[6]
Total current assets	810		801
Investments
Investment in equity method affiliates	107		105
Total investments	108		106
Property, Plant and Equipment
Property, plant and equipment	8,902		8,240
Accumulated depreciation, depletion and amortization	-2,538		-2,421
Total property, plant and equipment, net	6,364		5,819
Deferred Charges and Other Assets
Goodwill	542	[1]	545	[1]
Pension and other postretirement benefit assets	1,486	[6]	1,436	[6]
Intangible assets, net	79		82
Regulatory assets	379		285
Other	80	[6]	68	[6]
Total deferred charges and other assets	2,566		2,416
Total assets	9,848		9,142
Current Liabilities
Accounts payable	247		277
Payables to affiliates	41		45
Affiliated current borrowings	384		1,342
Accrued interest, payroll and taxes	194		209
Regulatory liabilities	75		79
Other	97	[6]	118	[6]
Total current liabilities	1,038		2,070
Long-Term Debt
Total long-term debt	2,594		1,198
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits	2,158		1,977
Regulatory liabilities	192		203
Other	300	[6]	267	[6]
Total deferred credits and other liabilities	2,650		2,447
Total liabilities	6,282		5,715
Commitments and Contingencies (see Note 22)
Equity
Membership interests	3,652		3,485
Accumulated other comprehensive loss	-86		-58
Total common shareholders' equity	3,566		3,427
Total liabilities and equity	$9,848		$9,142
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.
[3]	1 billion shares authorized; 585 million shares and 581 million shares outstanding at December 31, 2014 and 2013, respectively.
[4]	See Note 24 for amounts attributable to affiliates.
[5]	500,000 shares authorized at December 31, 2014 and 2013; 274,723 shares outstanding at December 31, 2014 and 2013
[6]	See Note 24 for amounts attributable to related parties.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Allowance - Customer Receivables	$34	$25
Allowance - Other	3	4
Common Stock, shares authorized	1,000,000,000	1,000,000,000
Common stock, shares outstanding	585,000,000	581,000,000
Virginia Electric and Power Company
Allowance - Customer Receivables	25	11
Allowance - Other	1	2
Common Stock, shares authorized	500,000	500,000
Common stock, shares outstanding	274,723	274,723
Dominion Gas Holdings, LLC
Allowance - Customer Receivables	4	5
Allowance - Other	$1	$1

Consolidated_Statements_Equity

Consolidated Statements Equity (USD $)		Total	IPO	Common Stock	Other Paid-In Capital	Retained Earnings		Accumulated Other Comprehensive Income (Loss)	Total Common Shareholders' Equity	Total Common Shareholders' Equity	Noncontrolling Interests	Noncontrolling Interests	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	Dominion Gas Holdings, LLC	Dominion Gas Holdings, LLC	Dominion Gas Holdings, LLC
Share data in Millions, unless otherwise specified										IPO		IPO		Common Stock	Other Paid-In Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)		Membership Interests	Accumulated Other Comprehensive Income (Loss)
Beginning Balance, value at Dec. 31, 2011																		$2,996,000,000	$3,167,000,000	($171,000,000)
Beginning Balance, value at Dec. 31, 2011		11,503,000,000		5,180,000,000	179,000,000	6,697,000,000		-610,000,000	11,446,000,000		57,000,000		8,750,000,000	5,738,000,000	1,111,000,000	1,882,000,000	19,000,000
Beginning Balance (in shares) at Dec. 31, 2011				570										275
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		329,000,000				318,000,000			318,000,000		11,000,000
Net income attributable to Dominion		302,000,000											1,050,000,000			1,050,000,000		459,000,000	459,000,000
Distributions																		-210,000,000	-210,000,000
Issuance of stock-employee and direct stock purchase plans (in shares)				4
Issuance of stock-employee and direct stock purchase plans		246,000,000		246,000,000					246,000,000
Stock awards and stock options exercised (net of change in unearned compensation) (in shares)				-1
Stock awards and stock options exercised (net of change in unearned compensation), value		26,000,000		26,000,000					26,000,000
Other stock issuances (in shares)	[1]			1
Other stock issuances, value	[1]	14,000,000		41,000,000	-27,000,000				14,000,000
Tax benefit from stock awards and stock options exercised		10,000,000			10,000,000				10,000,000				2,000,000		2,000,000
Dividends		-1,236,000,000				-1,225,000,000	[2]		-1,225,000,000		-11,000,000		-575,000,000			-575,000,000
Other comprehensive income, net of tax		-267,000,000						-267,000,000	-267,000,000				6,000,000				6,000,000	31,000,000		31,000,000
Beginning Balance, value at Dec. 31, 2012		10,625,000,000		5,493,000,000	162,000,000	5,790,000,000		-877,000,000	10,568,000,000		57,000,000		9,233,000,000	5,738,000,000	1,113,000,000	2,357,000,000	25,000,000
Beginning Balance, value at Dec. 31, 2012																		3,276,000,000	3,416,000,000	-140,000,000
Ending Balance (shares) at Dec. 31, 2012				576										275
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		502,000,000
Net income attributable to Dominion		495,000,000											287,000,000					138,000,000
Beginning Balance, value at Mar. 31, 2013
Beginning Balance, value at Dec. 31, 2012																		3,276,000,000	3,416,000,000	-140,000,000
Beginning Balance, value at Dec. 31, 2012		10,625,000,000		5,493,000,000	162,000,000	5,790,000,000		-877,000,000	10,568,000,000		57,000,000		9,233,000,000	5,738,000,000		2,357,000,000	25,000,000
Beginning Balance (in shares) at Dec. 31, 2012				576										275
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		1,720,000,000				1,714,000,000			1,714,000,000		6,000,000
Net income attributable to Dominion		1,697,000,000											1,138,000,000			1,138,000,000		461,000,000	461,000,000
Equity contribution from parent																		6,000,000	6,000,000
Distributions																		-398,000,000	-398,000,000
Issuance of stock-employee and direct stock purchase plans (in shares)				4
Issuance of stock-employee and direct stock purchase plans		278,000,000		278,000,000					278,000,000
Stock awards and stock options exercised (net of change in unearned compensation) (in shares)
Stock awards and stock options exercised (net of change in unearned compensation), value		12,000,000		12,000,000					12,000,000
Other stock issuances (in shares)	[3]			1
Other stock issuances, value	[3]	7,000,000		15,000,000	-8,000,000				7,000,000
Present value of stock purchase contract payments related to RSNs	[4]	-156,000,000			-154,000,000	-2,000,000			-156,000,000
Fairless lease buyout	[5]	-72,000,000		-15,000,000					-15,000,000		-57,000,000
Dividends		-1,325,000,000				-1,319,000,000	[2]		-1,319,000,000		-6,000,000		-596,000,000			-596,000,000
Other comprehensive income, net of tax		553,000,000						553,000,000	553,000,000				23,000,000				23,000,000	82,000,000		82,000,000
Beginning Balance, value at Dec. 31, 2013		11,642,000,000		5,783,000,000	0	6,183,000,000		-324,000,000	11,642,000,000		0		9,798,000,000	5,738,000,000	1,113,000,000	2,899,000,000	48,000,000
Beginning Balance, value at Dec. 31, 2013																		3,427,000,000	3,485,000,000	-58,000,000
Ending Balance (shares) at Dec. 31, 2013				581										275
Beginning Balance, value at Sep. 30, 2013
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		435,000,000
Net income attributable to Dominion		431,000,000											199,000,000					140,000,000
Beginning Balance, value at Dec. 31, 2013		11,642,000,000											9,798,000,000	5,738,000,000	1,113,000,000
Beginning Balance, value at Dec. 31, 2013																		3,427,000,000
Ending Balance (shares) at Dec. 31, 2013														275
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		385,000,000
Net income attributable to Dominion		379,000,000											324,000,000					164,000,000
Beginning Balance, value at Mar. 31, 2014
Beginning Balance, value at Dec. 31, 2013																		3,427,000,000	3,485,000,000	-58,000,000
Beginning Balance, value at Dec. 31, 2013		11,642,000,000		5,783,000,000		6,183,000,000		-324,000,000	11,642,000,000		0		9,798,000,000	5,738,000,000	1,113,000,000	2,899,000,000	48,000,000
Beginning Balance (in shares) at Dec. 31, 2013				581										275
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		1,326,000,000				1,323,000,000			1,323,000,000		3,000,000
Issuance of Dominion Midstream common units, net of offering costs			392,000,000							0		392,000,000
Net income attributable to Dominion		1,310,000,000											858,000,000			858,000,000		512,000,000	512,000,000
Equity contribution from parent																		1,000,000	1,000,000
Distributions																		-346,000,000	-346,000,000
Issuance of stock-employee and direct stock purchase plans (in shares)				3
Issuance of stock-employee and direct stock purchase plans		205,000,000		205,000,000					205,000,000
Stock awards and stock options exercised (net of change in unearned compensation), value		14,000,000		14,000,000					14,000,000
Other stock issuances (in shares)	[1]			1
Other stock issuances, value	[1]	14,000,000		14,000,000					14,000,000
Present value of stock purchase contract payments related to RSNs	[4]	-143,000,000		-143,000,000					-143,000,000
Dividends		-1,411,000,000				-1,411,000,000	[2]		-1,411,000,000				-603,000,000			-603,000,000
Other comprehensive income, net of tax		-92,000,000						-92,000,000	-92,000,000				2,000,000				2,000,000	-28,000,000		-28,000,000
Other		10,000,000		3,000,000					3,000,000		7,000,000
Beginning Balance, value at Dec. 31, 2014		11,957,000,000		5,876,000,000	0	6,095,000,000		-416,000,000	11,555,000,000		402,000,000		10,055,000,000	5,738,000,000	1,113,000,000	3,154,000,000	50,000,000
Beginning Balance, value at Dec. 31, 2014																		3,566,000,000	3,652,000,000	-86,000,000
Ending Balance (shares) at Dec. 31, 2014				585										275
Beginning Balance, value at Sep. 30, 2014
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		249,000,000
Net income attributable to Dominion		243,000,000											151,000,000					148,000,000
Beginning Balance, value at Dec. 31, 2014		11,957,000,000			0								10,055,000,000	5,738,000,000	1,113,000,000
Beginning Balance, value at Dec. 31, 2014																		$3,566,000,000
Ending Balance (shares) at Dec. 31, 2014														275
[1]	Contains shares issued in excess of principal amounts related to converted securities. See Note 17 for further information on convertible securities.
[2]	Includes subsidiary preferred dividends related to noncontrolling interests of $13 million, $17 million and $16 million in 2014 and 2013 and 2012, respectively
[3]	Primarily includes $28 million in shares issued in excess of principal amounts related to converted securities, net of reclassification from other paid-in capital. See Note 17 for further information on convertible securities.
[4]	See Note 17 for further information.
[5]	See Note 15 for further information.

Consolidated_Statements_of_Equ

Consolidated Statements of Equity (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement of Stockholders' Equity [Abstract]
Preferred dividends related to noncontrolling interest	$13	$17	$16
Shares issued in excess of principal amounts related to converted securities		$28

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Activities
Net income including noncontrolling interests	$1,326	$1,720	$329
Net income (loss) attributable to Dominion	1,310	1,697	302
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Impairment of generation assets	0	48	2,089
Net payments related to rate refunds	0	-5	-151
Depreciation and amortization	1,292	1,208	1,127
Depreciation, depletion and amortization (including nuclear fuel)	1,560	1,390	1,443
Deferred income taxes and investment tax credits	449	737	246
Gains on the sale of assets and businesses	-220	-122	-81
Charges associated with North Anna and offshore wind legislation	374	0	0
Charges associated with Liability Management Exercise	284	0	0
Charges associated with proposed settlement for ash pond closure costs	121	0	0
Other adjustments	-113	-129	-164
Changes in:
Accounts receivable	131	-98	292
Inventories	-43	-29	33
Deferred fuel and purchased gas costs, net	-180	102	368
Prepayments	24	123	-85
Accounts payable	-202	50	-61
Accrued interest, payroll and taxes	-41	-27	-12
Margin deposit assets and liabilities	361	-414	45
Other operating assets and liabilities	-392	87	-154
Net cash provided by operating activities	3,439	3,433	4,137
Investing Activities
Plant construction and other property additions (including nuclear fuel)	-5,345	-4,065	-4,145
Acquisition of solar development projects	-206	-39	0
Proceeds from sales of securities	1,235	1,476	1,356
Purchases of securities	-1,241	-1,493	-1,392
Proceeds from the sale of Brayton Point, Kincaid and equity method investment in Elwood	0	465	0
Proceeds from the sale of electric retail energy marketing business	187	0	0
Proceeds from Blue Racer	60	33	58
Proceeds from assignments of Marcellus acreage	60	18	0
Restricted cash equivalents	8	25	108
Other	36	-5	118
Net cash used in investing activities	-5,181	-3,458	-3,840
Financing Activities
Issuance (repayment) of short-term debt, net	848	-485	598
Issuance of short-term notes	400	400	400
Repayment of short-term notes	-400	-400	0
Issuance of long-term debt	6,085	4,135	1,500
Repayment and repurchase of long-term debt, including redemption premiums	-3,993	-1,245	-1,675
Repayment of long-term debt	0	-258	0
Acquisition of Juniper noncontrolling interest in Fairless	0	-923	0
Net proceeds from issuance of Dominion Midstream common units	392	0	0
Subsidiary preferred stock redemption	-259	0	0
Issuance of common stock	205	278	265
Common dividend payments	-1,398	-1,302	-1,209
Subsidiary preferred dividend payments	-11	-17	-16
Other	-125	-90	-14
Net cash provided by (used in) financing activities	1,744	93	-151
Increase in cash and cash equivalents	2	68	146
Cash and cash equivalents at beginning of year	316	248	102
Cash and cash equivalents at end of year	318	316	248
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts	889	852	913
Income taxes	72	56	-58
Significant noncash investing activities:
Accrued capital expenditures	315	375	388
Blue Racer
Investing Activities
Proceeds from Blue Racer	85	160	115
Virginia Electric and Power Company
Operating Activities
Net income (loss) attributable to Dominion	858	1,138	1,050
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Net payments related to rate refunds	0	-5	-151
Depreciation and amortization	915	853	782
Depreciation, depletion and amortization (including nuclear fuel)	1,090	1,016	927
Deferred income taxes and investment tax credits	396	240	502
Charges associated with North Anna and offshore wind legislation	374	0	0
Charges associated with proposed settlement for ash pond closure costs	121	0	0
Other adjustments	-35	-63	-70
Changes in:
Accounts receivable	-27	-124	126
Affiliated accounts receivable and payable	23	3	-2
Inventories	-45	-19	8
Deferred fuel and purchased gas costs, net	-191	93	378
Prepayments	-220	-9	18
Accounts payable	5	15	19
Accrued interest, payroll and taxes	-19	14	-22
Other operating assets and liabilities	-82	30	-77
Net cash provided by operating activities	2,248	2,329	2,706
Investing Activities
Plant construction and other property additions (including nuclear fuel)	-2,911	-2,394	-2,082
Purchases of nuclear fuel	-196	-139	-206
Purchases of securities	-574	-603	-638
Proceeds from sales of securities	549	572	626
Other	-2	-37	18
Net cash used in investing activities	-3,134	-2,601	-2,282
Financing Activities
Issuance (repayment) of short-term debt, net	519	-151	98
Issuance (repayment) of affiliated current borrowings, net	330	-338	248
Issuance of long-term debt	950	1,835	450
Repayment of long-term debt	-61	-470	-641
Subsidiary preferred stock redemption	-259	0	0
Common dividend payments	-590	-579	-559
Subsidiary preferred dividend payments	-11	-17	-16
Other	7	-20	-5
Net cash provided by (used in) financing activities	885	260	-425
Increase in cash and cash equivalents	-1	-12	-1
Cash and cash equivalents at beginning of year	16	28	29
Cash and cash equivalents at end of year	15	16	28
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts	383	328	376
Income taxes	386	427	225
Significant noncash investing activities:
Accrued capital expenditures	181	276	242
Dominion Gas Holdings, LLC
Operating Activities
Net income (loss) attributable to Dominion	512	461	459
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	197	188	176
Deferred income taxes and investment tax credits	216	102	294
Gains on the sale of assets and businesses	-124	-122	-176
Other adjustments	2	-3	2
Changes in:
Accounts receivable	-42	-17	63
Affiliated receivables	-1	2	-3
Inventories	-2	0	5
Prepayments	-99	13	-9
Accounts payable	-35	62	-52
Payables to affiliates	-4	8	-12
Accrued interest, payroll and taxes	-15	48	-43
Other operating assets and liabilities	-134	-44	-75
Net cash provided by operating activities	471	698	629
Investing Activities
Plant construction and other property additions (including nuclear fuel)	-719	-650	-928
Proceeds from sale of assets to an affiliate	47	113	0
Advances to affiliate, net	0	-5	-14
Proceeds from Blue Racer	20	19	25
Proceeds from assignments of Marcellus acreage	60	18	0
Other	-5	-14	-10
Net cash used in investing activities	-616	-460	-952
Financing Activities
Issuance (repayment) of affiliated current borrowings, net	-892	-545	549
Issuance of long-term debt	1,400	1,200	0
Repayment of long-term debt	0	-569	-10
Distribution payments	-346	-318	-210
Other	-16	-10	0
Net cash provided by (used in) financing activities	146	-242	329
Increase in cash and cash equivalents	1	-4	6
Cash and cash equivalents at beginning of year	8	12	6
Cash and cash equivalents at end of year	9	8	12
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts	23	31	43
Income taxes	266	148	67
Significant noncash investing activities:
Accrued capital expenditures	35	42	62
Extinguishment of affiliated long-term debt in exchange for assets sold to affiliate	67	0	187
Distribution of non-cash asset (account receivable) to parent	0	80	0
Proceeds from sale of assets to affiliate not yet received	0	30	61
Conversion of affiliated current borrowings to membership interests	0	0	61
Dominion Gas Holdings, LLC | Blue Racer
Investing Activities
Proceeds from Blue Racer	$1	$78	$0

Nature_of_Operations

Nature of Operations	12 Months Ended
	Dec. 31, 2014
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 and Dominion Gas. Virginia Power is a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and northeastern North Carolina. Virginia Power is a member of PJM, an RTO, and its electric transmission facilities are integrated into the PJM wholesale electricity markets. All of Virginia Power's stock is owned by Dominion. Dominion Gas is a holding company that conducts business activities through a regulated interstate natural gas transmission pipeline and underground storage system in the Northeast, mid-Atlantic and Midwest states, regulated gas transportation and distribution operations in Ohio, and gas gathering and processing activities primarily in West Virginia, Ohio and Pennsylvania. All of Dominion Gas' membership interests are held by Dominion.
	Dominion's operations also include an LNG import, transport and storage facility in Maryland, a preferred equity interest in which was contributed to Dominion Midstream in 2014, an equity investment in Atlantic Coast Pipeline and regulated gas transportation and distribution operations in West Virginia. Dominion's nonregulated operations include merchant generation, energy marketing and price risk management activities, retail energy marketing operations and an equity investment in Blue Racer.
	In October 2014, Dominion Midstream launched its initial public offering of 20,125,000 common units representing limited partner interests at a price of $21 per unit, which included an over-allotment option to purchase an additional 2,625,000 common units at the initial offering price, which was exercised in full by the underwriters. Dominion received $392 million in net proceeds from the sale of the units, after deducting underwriting discounts, structuring fees and estimated offering expenses. Dominion owns the general partner and 68.5% of the limited partner interests in Dominion Midstream, which owns a preferred equity interest and the general partner interest in Cove Point. The public's ownership interest in Dominion Midstream is reflected as non-controlling interest in Dominion's Consolidated Financial Statements.
	Dominion manages its daily operations through three primary operating segments: DVP, Dominion Generation and Dominion Energy. Dominion also reports a Corporate and Other segment, which includes its corporate, service company and other functions (including unallocated debt) and the net impact of operations that are discontinued, which is discussed in Note 3 and Note 25. 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.
	Virginia Power manages its daily operations through two primary operating segments: DVP and Dominion Generation. It also reports a Corporate and Other segment that 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.
	Dominion Gas manages its daily operations through one primary operating segment: Dominion Energy. It also reports a Corporate and Other segment that primarily includes specific items attributable to its operating segment that are not included in profit measures evaluated by executive management in assessing the segment's performance and the effect of certain items recorded at Dominion Gas as a result of the recognition of Dominion's basis in the net assets contributed.
	See Note 25 for further discussion of the Companies' operating segments.

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Significant Accounting Policies	SIGNIFICANT ACCOUNTING POLICIES
	General
	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, expenses and cash flows for the periods presented. Actual results may differ from those estimates.
	The Companies' Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of their respective majority-owned subsidiaries.
	The Companies report certain contracts, instruments and investments at fair value. See Note 6 for further information on fair value measurements.
	Dominion maintains pension and other postretirement benefit plans. Virginia Power and Dominion Gas participate in certain of these plans. See Note 21 for further information on these plans.
	Certain amounts in the 2013 and 2012 Consolidated Financial Statements and footnotes have been reclassified to conform to the 2014 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 and/or Dominion Gas, where applicable.
	Operating Revenue
	Operating revenue is recorded on the basis of services rendered, commodities delivered or contracts settled and includes amounts yet to be billed to customers. Dominion and Virginia Power collect sales, consumption and consumer utility taxes and Dominion Gas collects sales taxes; however, these amounts are excluded from revenue. Dominion's customer receivables at December 31, 2014 and 2013 included $564 million and $555 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to its utility customers. Virginia Power's customer receivables at December 31, 2014 and 2013 included $407 million and $395 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers. Dominion Gas' customer receivables at December 31, 2014 and 2013 included $127 million and $106 million, respectively, of accrued unbilled revenue based on estimated amounts of natural gas delivered but not yet billed to its customers.
	The primary types of sales and service activities reported as operating revenue for Dominion are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services;
	•	Nonregulated electric sales consist primarily of sales of electricity at market-based rates and contracted fixed rates, and associated derivative activity;
	•	Regulated gas sales consist primarily of state- and FERC-regulated natural gas sales and related distribution services;
	•	Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties, gas trading and marketing revenue and associated derivative activity;
	•	Gas transportation and storage consists primarily of regulated sales of gathering, transmission, distribution and storage services. Also included are regulated gas distribution charges to retail distribution service customers opting for alternate suppliers; and
	•	Other revenue consists primarily of sales of NGL production and condensate, extracted products and associated derivative activity. Other revenue also includes miscellaneous service revenue from electric and gas distribution operations, and gas processing and handling revenue.
	The primary types of sales and service activities reported as operating revenue for Virginia Power are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales and federally-regulated wholesale electric sales and electric transmission services; and
	•	Other revenue consists primarily of miscellaneous service revenue from electric distribution operations and miscellaneous revenue from generation operations, including sales of capacity and other commodities.
	The primary types of sales and service activities reported as operating revenue for Dominion Gas are as follows:
	•	Regulated gas sales consist primarily of state- and FERC-regulated natural gas sales and related distribution services;
	•	Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices and sales of gas purchased from third parties. Revenue from sales of gas production is recognized based on actual volumes of gas sold to purchasers and is reported net of royalties;
	•	Gas transportation and storage consists primarily of regulated sales of gathering, transmission, distribution and storage services. Also included are regulated gas distribution charges to retail distribution service customers opting for alternate suppliers;
	•	NGL revenue consists primarily of sales of NGL production and condensate, extracted products and associated derivative activity; and
	•	Other revenue consists primarily of miscellaneous service revenue, gas processing and handling revenue and gathering revenue.
	Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs
	Where permitted by regulatory authorities, the differences between Dominion's and Virginia Power's actual electric fuel and purchased energy expenses and Dominion's and Dominion Gas' purchased gas expenses and the related levels of recovery for these expenses in current rates are deferred and matched against recoveries in future periods. The deferral of costs in excess of current period fuel rate recovery is recognized as a regulatory asset, while rate recovery in excess of current period fuel expenses is recognized as a regulatory liability.
	Of the cost of fuel used in electric generation and energy purchases to serve utility customers, approximately 84% is currently subject to deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms.
	Virtually all of Dominion Gas', Cove Point's and Hope's natural gas purchases are either subject to deferral accounting or are recovered from the customer in the same accounting period as the sale.
	Income Taxes
	A consolidated federal income tax return is filed for Dominion and its subsidiaries, including Virginia Power and Dominion Gas' subsidiaries. In addition, where applicable, combined income tax returns for Dominion and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed.
	Although Dominion Gas is disregarded for income tax purposes, a provision for income taxes is recognized to reflect the inclusion of its business activities in the tax returns of its parent, Dominion. Virginia Power and Dominion Gas participate in intercompany tax sharing agreements with Dominion and its subsidiaries and current income taxes are based on taxable income or loss, determined on a separate company basis.
	Under the agreements, if a subsidiary incurs a net operating loss, recognition of current income tax benefits is limited to refunds of prior year taxes obtained by the carryback of the net operating loss or to the extent the net operating loss is absorbed by the taxable income of other Dominion consolidated group members. Otherwise, the net operating loss is carried forward and is recognized as a deferred tax asset until realized.
	Accounting for income taxes involves an asset and liability approach. Deferred income tax assets and liabilities are provided, representing future effects on income taxes for temporary differences between the bases of assets and liabilities for financial reporting and tax purposes. Accordingly, deferred taxes are recognized for the future consequences of different treatments used for the reporting of transactions in financial accounting and income tax returns. The Companies establish a valuation allowance when it is more-likely-than-not that all, or a portion, of a deferred tax asset will not be realized. Where the treatment of temporary differences is different for rate-regulated operations, a regulatory asset is recognized if it is probable that future revenues will be provided for the payment of deferred tax liabilities.
	The Companies recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not to be realized, assuming that the position will be examined by tax authorities with full knowledge of all relevant information.
	If it is not more-likely-than-not that a tax position, or some portion thereof, will be sustained, the related tax benefits are not recognized in the financial statements. Unrecognized tax benefits may result in an increase in income taxes payable, a reduction of income tax refunds receivable or changes in deferred taxes. Also, when uncertainty about the deductibility of an amount is limited to the timing of such deductibility, the increase in income taxes payable (or reduction in tax refunds receivable) is accompanied by a decrease in deferred tax liabilities. Except when such amounts are presented net with amounts receivable from or amounts prepaid to tax authorities, noncurrent income taxes payable related to unrecognized tax benefits are classified in other deferred credits and other liabilities on the consolidated balance sheets and current payables are included in accrued interest, payroll and taxes on the consolidated balance sheets.
	The Companies recognize interest on underpayments and overpayments of income taxes in interest expense and other income, respectively. Penalties are also recognized in other income.
	Dominion's, Virginia Power's and Dominion Gas' interest and penalties were immaterial in 2014, 2013 and 2012.
	At December 31, 2014, Virginia Power's Consolidated Balance Sheet included $225 million of federal and state income taxes receivable, $13 million of noncurrent state income taxes receivable and $38 million of noncurrent federal and state income taxes payable.
	At December 31, 2013, Virginia Power's Consolidated Balance Sheet included $3 million of state income taxes receivable, $22 million of federal and state income taxes payable, $12 million of noncurrent state income taxes receivable and $28 million of noncurrent federal and state income taxes payable.
	At December 31, 2014, Dominion Gas' Consolidated Balance Sheet included $96 million of federal and state income taxes receivable, $14 million of state income taxes payable, $7 million of noncurrent state income taxes payable and $20 million noncurrent state income taxes receivable.
	At December 31, 2013, Dominion Gas' Consolidated Balance Sheet included $17 million of federal income taxes payable, $23 million of state income taxes payable, $1 million of state income taxes receivable, $7 million of noncurrent state income taxes payable and $20 million noncurrent state income taxes receivable.
	Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold.
	Cash and Cash Equivalents
	Current banking arrangements generally do not require checks to be funded until they are presented for payment. The following table illustrates the checks outstanding but not yet presented for payment and recorded in accounts payable for the Companies:
	Year Ended December 31,	2014	2013
	(millions)
	Dominion	$42	$38
	Virginia Power	20	21
	Dominion Gas	9	7
	For purposes of the Consolidated Statements of Cash Flows, cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less.
	Derivative Instruments
	Dominion and Virginia Power use derivative instruments such as futures, swaps, forwards, options and FTRs to manage the commodity, currency exchange and financial market risks of their business operations. Dominion Gas uses derivative instruments such as physical and financial forwards, futures and swaps to manage commodity price and interest rate risks.
	All derivatives, except those for which an exception applies, are required to be reported in the Consolidated Balance Sheets at fair value. Derivative contracts representing unrealized gain positions and purchased options are reported as derivative assets. Derivative contracts representing unrealized losses and options sold are reported as derivative liabilities. One of the exceptions to fair value accounting, normal purchases and normal sales, may be elected when the contract satisfies certain criteria, including a requirement that physical delivery of the underlying commodity is probable. Expenses and revenues resulting from deliveries under normal purchase contracts and normal sales contracts, respectively, are included in earnings at the time of contract performance.
	The Companies do not offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. Dominion had margin assets of $287 million and $620 million associated with cash collateral at December 31, 2014 and 2013, respectively. Dominion had margin liabilities of $34 million and $2 million associated with cash collateral at December 31, 2014 and 2013, respectively. Virginia Power had margin assets of $6 million and $11 million associated with cash collateral at December 31, 2014 and 2013, respectively. Virginia Power did not have any margin liabilities associated with cash collateral at December 31, 2014 or 2013. Dominion Gas did not have any margin assets or liabilities related to cash collateral at December 31, 2014 or 2013. See Note 7 for further information about derivatives.
	To manage price risk, Dominion and Virginia Power hold certain derivative instruments that are not designated as hedges for accounting purposes. However, to the extent Dominion and Virginia Power do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices, interest rates and foreign exchange rates. As part of Dominion’s strategy to market energy and manage related risks, it formerly managed a portfolio of commodity-based financial derivative instruments held for trading purposes. Dominion used established policies and procedures to manage the risks associated with price fluctuations in these energy commodities and used various derivative instruments to reduce risk by creating offsetting market positions. In the second quarter of 2013, Dominion commenced a repositioning of its producer services business. The repositioning was completed in the first quarter of 2014 and resulted in the termination of natural gas trading and certain energy marketing activities.
	Statement of Income Presentation:
	•	Derivatives Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue on a net basis.
	•	Derivatives Not Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses or interest and related charges based on the nature of the underlying risk.
	In Virginia Power's generation operations, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities for jurisdictions subject to cost-based rate regulation. Realized gains or losses on the derivative instruments are generally recognized when the related transactions impact earnings.
	DERIVATIVE INSTRUMENTS DESIGNATED AS HEDGING INSTRUMENTS
	The Companies designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. For all derivatives designated as hedges, the Companies formally document the relationship between the hedging instrument and the hedged item, as well as the risk management objective and the strategy for using the hedging instrument. The Companies assess whether the hedging relationship between the derivative and the hedged item is highly effective at offsetting changes in cash flows or fair values both at the inception of the hedging relationship and on an ongoing basis. Any change in the fair value of the derivative that is not effective at offsetting changes in the cash flows or fair values of the hedged item is recognized currently in earnings. Also, the Companies may elect to exclude certain gains or losses on hedging instruments from the assessment of hedge effectiveness, such as gains or losses attributable to changes in the time value of options or changes in the difference between spot prices and forward prices, thus requiring that such changes be recorded currently in earnings. Hedge accounting is discontinued prospectively for derivatives that cease to be highly effective hedges. For derivative instruments that are accounted for as fair value hedges or cash flow hedges, the cash flows from the derivatives and from the related hedged items are classified in operating cash flows.
	Cash Flow Hedges-A majority of the Companies' hedge strategies represents cash flow hedges of the variable price risk associated with the purchase and sale of electricity, natural gas, NGLs and other energy-related products. The Companies also use foreign currency contracts to hedge the variability in foreign exchange rates and interest rate swaps to hedge their exposure to variable interest rates on long-term debt. For transactions in which the Companies are hedging the variability of cash flows, changes in the fair value of the derivatives are reported in AOCI, to the extent they are effective at offsetting changes in the hedged item. Any derivative gains or losses reported in AOCI are reclassified to earnings when the forecasted item is included in earnings, or earlier, if it becomes probable that the forecasted transaction will not occur. For cash flow hedge transactions, hedge accounting is discontinued if the occurrence of the forecasted transaction is no longer probable.
Dominion entered into interest rate derivative instruments to hedge its forecasted interest payments related to planned debt issuances in 2013 and 2014. These interest rate derivatives were designated by Dominion as cash flow hedges in 2012 and 2013, prior to the formation of Dominion Gas. For the purposes of the Dominion Gas financial statements, the derivative balances, AOCI balance, and any income statement impact related to these interest rate derivative instruments entered into by Dominion have been, and will continue to be, included in the Dominion Gas' Consolidated Financial Statements as the forecasted interest payments related to the debt issuances will now occur at Dominion Gas.
Fair Value Hedges-Dominion also uses fair value hedges to mitigate the fixed price exposure inherent in certain firm commodity commitments and commodity inventory. In addition, Dominion and Virginia Power have designated interest rate swaps as fair value hedges on certain fixed rate long-term debt to manage interest rate exposure. For fair value hedge transactions, changes in the fair value of the derivative are generally offset currently in earnings by the recognition of changes in the hedged item's fair value. Derivative gains and losses from the hedged item are reclassified to earnings when the hedged item is included in earnings, or earlier, if the hedged item no longer qualifies for hedge accounting. Hedge accounting is discontinued if the hedged item no longer qualifies for hedge accounting. See Note 6 for further information about fair value measurements and associated valuation methods for derivatives. See Note 7 for further information on derivatives.
Property, Plant and Equipment
Property, plant and equipment is recorded at lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs such as asset retirement costs, capitalized interest and, for certain operations subject to cost-of-service rate regulation, AFUDC and overhead costs. The cost of repairs and maintenance, including minor additions and replacements, is generally charged to expense as it is incurred.
In 2014, 2013 and 2012, Dominion capitalized interest costs and AFUDC to property, plant and equipment of $80 million, $66 million and $91 million, respectively. In 2014, 2013 and 2012, Virginia Power capitalized AFUDC to property, plant and equipment of $39 million, $33 million and $31 million, respectively. In 2014, 2013 and 2012, Dominion Gas capitalized AFUDC to property, plant and equipment of $1 million, $5 million and $23 million, respectively.
Under Virginia law, certain Virginia jurisdictional projects qualify for current recovery of AFUDC through rate adjustment clauses. AFUDC on these projects is calculated and recorded as a regulatory asset and is not capitalized to property, plant and equipment. In 2014, 2013 and 2012, Virginia Power recorded $8 million, $32 million and $37 million of AFUDC related to these projects, respectively.
For property subject to cost-of-service rate regulation, including Virginia Power electric distribution, electric transmission, and generation property, Dominion Gas natural gas distribution and transmission property, and for certain Dominion natural gas property, the undepreciated cost of such property, less salvage value, is generally charged to accumulated depreciation at retirement. Cost of removal collections from utility customers not representing AROs are recorded as regulatory liabilities. For property subject to cost-of-service rate regulation that will be abandoned significantly before the end of its useful life, the net carrying value is reclassified from plant-in-service when it becomes probable it will be abandoned.
For property that is not subject to cost-of-service rate regulation, including nonutility property, cost of removal not associated with AROs is charged to expense as incurred. The Companies also record gains and losses upon retirement based upon the difference between the proceeds received, if any, and the property's net book value at the retirement date.
Depreciation of property, plant and equipment is computed on the straight-line method based on projected service lives. The Companies' average composite depreciation rates on utility property, plant and equipment are as follows:
Year Ended December 31,	2014	2013	2012
(percent)
Dominion
Generation	2.66	2.71	2.62
Transmission	2.38	2.36	2.17
Distribution	3.12	3.13	3.17
Storage	2.39	2.43	2.59
Gas gathering and processing	2.81	2.39	2.49
General and other	3.62	3.82	4.55
Virginia Power
Generation	2.66	2.71	2.62
Transmission	2.34	2.28	1.98
Distribution	3.34	3.33	3.32
General and other	3.29	3.51	4.32
Dominion Gas
Transmission	2.4	2.43	2.35
Distribution	2.47	2.5	2.66
Storage	2.4	2.43	2.58
Gas gathering and processing	2.82	2.39	2.5
General and other	5.77	5.93	6.09
In 2013, Virginia Power revised its depreciation rates to reflect the results of a new depreciation study. This change resulted in an increase of $19 million ($12 million after-tax) in depreciation and amortization expense in Virginia Power's Consolidated Statements of Income.
In 2014, Virginia Power also made a one-time adjustment to depreciation expense as ordered by the Virginia Commission. This adjustment resulted in an increase of $38 million ($23 million after-tax) in depreciation and amortization expense in Virginia Power’s Consolidated Statements of Income.
In 2013, Dominion Gas revised the depreciation rates for East Ohio to reflect the results of a new depreciation study. This change resulted in a decrease of $8 million ($5 million after-tax) in depreciation and amortization expense in Dominion Gas' Consolidated Statements of Income.
Dominion's nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives:
Asset	Estimated Useful Lives
Merchant generation-nuclear	44 years
Merchant generation-other	15-36 years
General and other	5-59 years
Depreciation and amortization related to Virginia Power's and Dominion Gas' nonutility property, plant and equipment and E&P properties was immaterial for the years ended December 31, 2014, 2013 and 2012.
Nuclear fuel used in electric generation is amortized over its estimated service life on a units-of-production basis. Dominion and Virginia Power report the amortization of nuclear fuel in electric fuel and other energy-related purchases expense in their Consolidated Statements of Income and in depreciation and amortization in their Consolidated Statements of Cash Flows.
Long-Lived and Intangible Assets
The Companies perform an evaluation for impairment whenever events or changes in circumstances indicate that the carrying amount of long-lived assets or intangible assets with finite lives may not be recoverable. A long-lived or intangible asset is written down to fair value if the sum of its expected future undiscounted cash flows is less than its carrying amount. Intangible assets with finite lives are amortized over their estimated useful lives. See Note 6 for a discussion of impairments related to certain long-lived assets and intangible assets with finite lives.
Regulatory Assets and Liabilities
The accounting for Dominion's and Dominion Gas' regulated gas and Virginia Power's regulated electric operations differs from the accounting for nonregulated operations in that they are required to reflect the effect of rate regulation in their Consolidated Financial Statements. For regulated businesses subject to federal or state cost-of-service rate regulation, regulatory practices that assign costs to accounting periods may differ from accounting methods generally applied by nonregulated companies. When it is probable that regulators will permit the recovery of current costs through future rates charged to customers, these costs that otherwise would be expensed by nonregulated companies are deferred as regulatory assets. Likewise, regulatory liabilities are recognized when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have yet to be incurred. Generally, regulatory assets and liabilities are amortized into income over the period authorized by the regulator.
The Companies evaluate whether or not recovery of their regulatory assets through future rates is probable and make various assumptions in their analyses. The expectations of future recovery are generally based on orders issued by regulatory commissions, legislation or historical experience, as well as discussions with applicable regulatory authorities and legal counsel. If recovery of a regulatory asset is determined to be less than probable, it will be written off in the period such assessment is made.
Asset Retirement Obligations
The Companies recognize AROs at fair value as incurred or when sufficient information becomes available to determine a reasonable estimate of the fair value of future retirement activities to be performed. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. At least annually, the Companies evaluate the key assumptions underlying their AROs including estimates of the amounts and timing of future cash flows associated with retirement activities. AROs are adjusted when significant changes in these assumptions are identified. Dominion and Dominion Gas report accretion of AROs and depreciation on asset retirement costs associated with their natural gas pipeline and storage well assets as an adjustment to the related regulatory liabilities when revenue is recoverable from customers for AROs. Virginia Power reports accretion of AROs and depreciation on asset retirement costs associated with decommissioning its nuclear power stations as an adjustment to the regulatory liability for certain jurisdictions. Accretion of all other AROs and depreciation of all other asset retirement costs is reported in other operations and maintenance expense and depreciation expense in the Consolidated Statements of Income.
Debt Issuance Costs
The Companies defer and amortize debt issuance costs and debt premiums or discounts over the expected lives of the respective debt issues, considering maturity dates and, if applicable, redemption rights held by others. Deferred debt issuance costs are recorded as an asset and classified in other current assets and other deferred charges and other assets in the Consolidated Balance Sheets. Unamortized costs associated with redemptions of debt securities prior to stated maturity dates are generally recognized and recorded in interest expense immediately. As permitted by regulatory authorities, gains or losses resulting from the refinancing of debt allocable to utility operations subject to cost-based rate regulation are deferred and amortized over the lives of the new issuances.
Investments
MARKETABLE EQUITY AND DEBT SECURITIES
Dominion accounts for and classifies investments in marketable equity and debt securities as trading or available-for-sale securities. Virginia Power classifies investments in marketable equity and debt securities as available-for-sale securities.
•	Trading securities include marketable equity and debt securities held by Dominion in rabbi trusts associated with certain deferred compensation plans. These securities are reported in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income.
•	Available-for-sale securities include all other marketable equity and debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any other-than-temporary impairments) on investments held in Virginia Power's nuclear decommissioning trusts are recorded to a regulatory liability for certain jurisdictions subject to cost-based regulation. For all other available-for-sale securities, including those held in Dominion's merchant generation nuclear decommissioning trusts, net realized gains and losses (including any other-than-temporary impairments) are included in other income and unrealized gains and losses are reported as a component of AOCI, after-tax.
In determining realized gains and losses for marketable equity and debt securities, the cost basis of the security is based on the specific identification method.
NON-MARKETABLE INVESTMENTS
The Companies account for illiquid and privately held securities for which market prices or quotations are not readily available under either the equity or cost method. Non-marketable investments include:
•	Equity method investments when the Companies have the ability to exercise significant influence, but not control, over the investee. Dominion's investments are included in investments in equity method affiliates and Virginia Power's investments are included in other investments in their Consolidated Balance Sheets. The Companies record equity method adjustments in other income in the Consolidated Statements of Income including: their proportionate share of investee income or loss, gains or losses resulting from investee capital transactions, amortization of certain differences between the carrying value and the equity in the net assets of the investee at the date of investment and other adjustments required by the equity method.
•	Cost method investments when Dominion and Virginia Power do not have the ability to exercise significant influence over the investee. Dominion's and Virginia Power's investments are included in other investments and nuclear decommissioning trust funds.
OTHER-THAN-TEMPORARY IMPAIRMENT
Dominion and Virginia Power periodically review their investments to determine whether a decline in fair value should be considered other-than-temporary. If a decline in fair value of any security is determined to be other-than-temporary, the security is written down to its fair value at the end of the reporting period.
Decommissioning Trust Investments-Special Considerations
•	The recognition provisions of the FASB's other-than-temporary impairment guidance apply only to debt securities classified as available-for-sale or held-to-maturity, while the presentation and disclosure requirements apply to both debt and equity securities.
•	Debt Securities- Using information obtained from their nuclear decommissioning trust fixed-income investment managers, Dominion and Virginia Power record in earnings any unrealized loss for a debt security when the manager intends to sell the debt security or it is more-likely-than-not that the manager will have to sell the debt security before recovery of its fair value up to its cost basis. If that is not the case, but the debt security is deemed to have experienced a credit loss, Dominion and Virginia Power record the credit loss in earnings and any remaining portion of the unrealized loss in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors.
•	Equity securities and other investments- Dominion's and Virginia Power's method of assessing other-than-temporary declines requires demonstrating the ability to hold individual securities for a period of time sufficient to allow for the anticipated recovery in their market value prior to the consideration of the other criteria mentioned above. Since Dominion and Virginia Power have limited ability to oversee the day-to-day management of nuclear decommissioning trust fund investments, they do not have the ability to ensure investments are held through an anticipated recovery period. Accordingly, they consider all equity and other securities as well as non-marketable investments held in nuclear decommissioning trusts with market values below their cost bases to be other-than-temporarily impaired.
Inventories
Materials and supplies and fossil fuel inventories are valued primarily using the weighted-average cost method. Stored gas inventory for Dominion Gas used in East Ohio gas distribution operations is valued using the LIFO method. Under the LIFO method, stored gas inventory was valued at $12 million and $7 million at December 31, 2014 and December 31, 2013, respectively. Based on the average price of gas purchased during 2014 and 2013, the cost of replacing the current portion of stored gas inventory exceeded the amount stated on a LIFO basis by approximately $98 million and $77 million, respectively. Stored gas inventory for Dominion held by Hope and certain nonregulated gas operations is valued using the weighted-average cost method.
Gas Imbalances
Natural gas imbalances occur when the physical amount of natural gas delivered from, or received by, a pipeline system or storage facility differs from the contractual amount of natural gas delivered or received. Dominion and Dominion Gas value these imbalances due to, or from, shippers and operators at an appropriate index price at period end, subject to the terms of its tariff for regulated entities. Imbalances are primarily settled in-kind. Imbalances due to Dominion and Dominion Gas from other parties are reported in other current assets and imbalances that Dominion and Dominion Gas owe to other parties are reported in other current liabilities in the Consolidated Balance Sheets.
Goodwill
Dominion and Dominion Gas evaluate goodwill for impairment annually as of April 1 and whenever an event occurs or circumstances change in the interim that would more-likely-than-not reduce the fair value of a reporting unit below its carrying amount.

Acquisitions_and_Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2014
Business Combinations, Discontinued Operations and Disposal Groups [Abstract]
Acquisitions and Dispositions	ACQUISITIONS AND DISPOSITIONS
	Dominion
	Acquisition of Solar Development Projects
	In March 2014, Dominion acquired 100% of the equity interests of six solar development projects in California from Recurrent Energy Development Holdings, LLC for approximately $50 million in cash. The projects cost approximately $446 million to construct, including the initial acquisition cost. The facilities, which began commercial operations in the fourth quarter of 2014, generate approximately 139 MW.
	In November 2014, Dominion acquired 100% of the equity interests of a solar project in California from CSI Project Holdco, LLC for approximately $79 million in cash. The project costs approximately $80 million to construct, including the initial acquisition cost. The facility, which began commercial operations in the fourth quarter of 2014, generates approximately 20 MW.
	In December 2014, Dominion acquired 100% of the equity interests of a solar project in California from EDF Renewable Development, Inc. for approximately $71 million in cash.  The project is expected to cost approximately $73 million to construct, including the initial acquisition cost. The facility, which began commercial operations in January 2015, generates approximately 20 MW.
	The purchase price for each of these acquisitions was allocated to Property, Plant and Equipment.
	In September 2014, Dominion entered into agreements to acquire 100% of the equity interests in two additional solar projects in California from EDF Renewable Development, Inc. for approximately $175 million in cash. The acquisitions are expected to close in the first half of 2015 prior to the projects commencing operations. The projects are expected to cost approximately $185 million once constructed, including the initial acquisition cost. Upon completion, the facilities are expected to generate approximately 42 MW.
	These acquisitions provide Dominion with a large utility-scale solar presence and significantly increase its solar generation portfolio. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for the projects. Dominion has claimed or expects to claim federal investment tax credits on the projects.
	Acquisition of CGT
	In January 2015, Dominion completed the acquisition of 100% of the equity interests of CGT from SCANA Corporation for approximately $495 million in cash, subject to final acquired working capital adjustments. CGT owns and operates nearly 1,500 miles of FERC-regulated interstate natural gas pipeline in South Carolina and southeastern Georgia. This acquisition supports Dominion's natural gas expansion into the Southeast. The acquired assets of CGT will be included in the Dominion Energy operating segment. Subject to board approvals by Dominion and Dominion Midstream, Dominion expects to contribute CGT into Dominion Midstream for a combination of debt and Dominion Midstream common units during the first half of 2015. The allocation of the purchase price to individual assets is under evaluation by management and has not been finalized.
	Sale of Electric Retail Energy Marketing Business
	In March 2014, Dominion completed the sale of its electric retail energy marketing business. The proceeds were approximately $187 million, net of transaction costs. The sale resulted in a gain, subject to post-closing adjustments, of approximately $100 million ($57 million after-tax) net of a $31 million write-off of goodwill, and is included in other operations and maintenance expense in Dominion's Consolidated Statements of Income. The sale of the electric retail energy marketing business did not qualify for discontinued operations classification.
	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 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. See Note 6 for other impairments related to these power stations.
	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:
	Year Ended December 31,	2013				2012
	(millions)
	Operating revenue	$	304			$	258
	Loss before income taxes	(135		)	(1)	(1,768		)	(2)
	(1) Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013.
	(2) Includes a long-lived asset impairment charge of $1.6 billion.
	Sale of Salem Harbor and State Line
	In August 2012, Dominion completed the sale of Salem Harbor. In the second quarter of 2012, the assets and liabilities to be disposed were classified as held for sale and adjusted to their estimated fair value less cost to sell. Also during the second quarter of 2012, Dominion completed the sale of State Line, which ceased operations in March 2012. See Note 6 for impairments related to these power stations.
	The following table presents selected information regarding the results of operations of Salem Harbor and State Line, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
	Year Ended December 31,	2012
	(millions)
	Operating revenue	$	57
	Loss before income taxes	(49		)
	Dominion and Dominion Gas
	Blue Racer
	See Note 9 for a discussion of transactions related to Blue Racer.
	Marcellus Acreage
	See Note 10 for a discussion of assignments of Marcellus acreage.

Operating_Revenue

Operating Revenue	12 Months Ended
	Dec. 31, 2014
Regulated and Unregulated Operating Revenue [Abstract]
Operating Revenue	OPERATING REVENUE
	The Companies' operating revenue consists of the following:
	Year Ended December 31,	2014		2013		2012
	(millions)
	Dominion
	Electric sales:
	Regulated	$	7,460	$	7,193	$	7,102
	Nonregulated	1,839		2,511		2,483
	Gas sales:
	Regulated	334		323		250
	Nonregulated	751		930		1,071
	Gas transportation and storage	1,543		1,535		1,401
	Other	509		628		528
	Total operating revenue	$	12,436	$	13,120	$	12,835
	Virginia Power
	Regulated electric sales	$	7,460	$	7,193	$	7,102
	Other	119		102		124
	Total operating revenue	$	7,579	$	7,295	$	7,226
	Dominion Gas
	Gas sales:
	Regulated	$	209	$	202	$	138
	Nonregulated	26		32		28
	Gas transportation and storage	1,353		1,338		1,188
	NGL revenue	212		292		275
	Other	98		73		48
	Total operating revenue	$	1,898	$	1,937	$	1,677

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES
	Judgment and the use of estimates are required in developing the provision for income taxes and reporting of tax-related assets and liabilities. The interpretation of tax laws involves uncertainty, since tax authorities may interpret the laws differently. The Companies are routinely audited by federal and state tax authorities. Ultimate resolution of income tax matters may result in favorable or unfavorable impacts to net income and cash flows, and adjustments to tax-related assets and liabilities could be material.
	In December 2014, U.S. federal legislation was enacted that provides an extension of the 50% bonus depreciation allowance for qualifying capital expenditures incurred through 2014.
	Continuing Operations
	Details of income tax expense for continuing operations including noncontrolling interests were as follows:
		Dominion									Virginia Power									Dominion Gas
	Year Ended December 31,	2014			2013			2012			2014			2013			2012			2014		2013			2012
	(millions)
	Current:
	Federal	$	(11	)	$	317		$	43		$	85		$	357		$	70		$	86	$	158		$	(8	)
	State	14			110			84			67			62			81			32		41			2
	Total current expense (benefit)	3			427			127			152			419			151			118		199			(6		)
	Deferred:
	Federal
	Taxes before operating loss carryforwards and investment tax credits	956			563			645			381			224			482			192		92			257
	Tax benefit of operating loss carryforwards	(352		)	(18		)	—			—			—			—			—		—			—
	Investment tax credits	(152		)	(48		)	—			—			—			—			—		—			—
	State	(2		)	(31		)	40			16			17			21			24		10			37
	Total deferred expense	450			466			685			397			241			503			216		102			294
	Amortization of deferred investment tax credits	(1		)	(1		)	(1		)	(1		)	(1		)	(1		)	—		—			—
	Total income tax expense	$	452		$	892		$	811		$	548		$	659		$	653		$	334	$	301		$	288
	For continuing operations including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to the Companies' effective income tax rate as follows:
		Dominion						Virginia Power						Dominion Gas
	Year Ended December 31,	2014		2013		2012		2014		2013		2012		2014		2013		2012
	U.S. statutory rate	35	%	35	%	35	%	35	%	35	%	35	%	35	%	35	%	35	%
	Increases (reductions) resulting from:
	State taxes, net of federal benefit	—		2.1		4.2		3.8		3.1		3.9		4.4		4.3		3.4
	Investment tax credits	(8.6	)	(1.8	)	—		—		—		—		—		—		—
	Production tax credits	(1.2	)	(0.6	)	(0.5	)	(0.6	)	(0.2	)	—		—		—		—
	Valuation allowances	0.7		(0.1	)	(0.7	)	—		—		—		—		—		—
	AFUDC - equity	—		(0.6	)	(0.9	)	—		(0.8	)	(0.9	)	—		(0.1	)	(0.6	)
	Employee stock ownership plan deduction	(0.9	)	(0.6	)	(0.7	)	—		—		—		—		—		—
	Other, net	0.4		(0.4	)	(0.6	)	0.8		(0.4	)	0.3		0.1		0.3		0.7
	Effective tax rate	25.4	%	33	%	35.8	%	39	%	36.7	%	38.3	%	39.5	%	39.5	%	38.5	%
	Dominion's effective tax rate in 2014 reflects the recognition of state tax credits and previously unrecognized tax benefits due to the expiration of statutes of limitations.
	The Companies' deferred income taxes consist of the following:
		Dominion						Virginia Power						Dominion Gas
	At December 31,	2014			2013			2014			2013			2014			2013
	(millions)
	Deferred income taxes:
	Total deferred income tax assets	$	2,023		$	2,142		$	500		$	462		$	227		$	216
	Total deferred income tax liabilities	8,663			8,463			4,915			4,498			2,289			2,103
	Total net deferred income tax liabilities	$	6,640		$	6,321		$	4,415		$	4,036		$	2,062		$	1,887
	Total deferred income taxes:
	Plant and equipment, primarily depreciation method and basis differences	$	5,895		$	5,383		$	3,965		$	3,628		$	1,417		$	1,266
	Nuclear decommissioning	1,241			1,136			474			441			—			—
	Deferred state income taxes	659			606			299			285			207			182
	Federal benefit of deferred state income taxes	(231		)	(212		)	(105		)	(100		)	(72		)	(64		)
	Deferred fuel, purchased energy and gas costs	27			(33		)	18			(50		)	7			13
	Pension benefits	272			435			(77		)	(52		)	567			522
	Other postretirement benefits	(17		)	(78		)	13			(3		)	(12		)	(13		)
	Loss and credit carryforwards	(1,434		)	(797		)	(116		)	(106		)	(10		)	(10		)
	Valuation allowances	87			69			—			—			—			—
	Partnership basis differences	304			125			—			—			42			42
	Other	(163		)	(313		)	(56		)	(7		)	(84		)	(51		)
	Total net deferred income tax liabilities	$	6,640		$	6,321		$	4,415		$	4,036		$	2,062		$	1,887
	At December 31, 2014, Dominion had the following deductible loss and credit carryforwards:
	•	Federal loss carryforwards of $2.2 billion that expire if unutilized during the period 2021 through 2034;
	•	Federal investment tax credits of $245 million that expire if unutilized during the period 2033 through 2034;
	•	Federal production and other tax credits of $65 million that expire if unutilized during the period 2031 through 2034;
	•	State loss carryforwards of $1.7 billion that expire if unutilized during the period 2018 through 2034. A valuation allowance on $962 million of these carryforwards has been established;
	•	State minimum tax credits of $194 million that do not expire; and
	•	State investment tax credits of $29 million that expire if unutilized during the period 2016 through 2019.
	At December 31, 2014, Virginia Power had the following deductible loss and credit carryforwards:
•	Federal loss carryforwards of $279 million that expire if unutilized during the period 2031 through 2033; and
•	Federal production and other tax credits of $14 million that expire if unutilized during the period 2031 through 2034.
At December 31, 2014, Dominion Gas had the following deductible loss carryforwards:
•	Federal loss carryforwards of $25 million that expire if unutilized during the period 2031 through 2033; and
•	State loss carryforwards of $4 million that expire if unutilized during the period 2031 through 2032.
Dominion Gas had no credit carryforwards at December 31, 2014.
A reconciliation of changes in the Companies' unrecognized tax benefits follows:
	Dominion									Virginia Power									Dominion Gas
	2014			2013			2012			2014			2013			2012			2014		2013			2012
(millions)
Balance at January 1	$	222		$	293		$	347		$	39		$	57		$	114		$	29	$	30		$	30
Increases-prior period positions	24			17			28			2			12			4			—		—			—
Decreases-prior period positions	(26		)	(99		)	(106		)	(16		)	(42		)	(80		)	—		(1		)	—
Increases-current period positions	16			30			43			11			14			24			—		—			—
Decreases-current period positions	—			(5		)	—			—			—			—			—		—			—
Settlements with tax authorities	—			(2		)	(4		)	—			(2		)	(4		)	—		—			—
Expiration of statutes of limitations	(91		)	(12		)	(15		)	—			—			(1		)	—		—			—
Balance at December 31	$	145		$	222		$	293		$	36		$	39		$	57		$	29	$	29		$	30
Certain unrecognized tax benefits, or portions thereof, if recognized, would affect the effective tax rate. Changes in these unrecognized tax benefits may result from remeasurement of amounts expected to be realized, settlements with tax authorities and expiration of statutes of limitations. For Dominion and its subsidiaries, these unrecognized tax benefits were $77 million, $126 million and $167 million at December 31, 2014, 2013 and 2012, respectively. For Dominion, the change in these unrecognized tax benefits decreased income tax expense by $47 million and $29 million in 2014 and 2013, respectively, and increased income tax expense by $1 million in 2012. For Virginia Power, these unrecognized tax benefits were $8 million at December 31, 2014 and 2013, and $13 million at December 31, 2012. For Virginia Power, the change in these unrecognized tax benefits decreased income tax expense by less than $1 million in 2014 and increased income tax expense by $4 million and $1 million in 2013 and 2012, respectively. For Dominion Gas, these unrecognized tax benefits were $19 million at December 31, 2014 and 2013 and $20 million at December 31, 2012. For Dominion Gas, the change in these unrecognized tax benefits affected income tax expense by less than $1 million in 2014, 2013 and 2012.
In January 2012, the Appellate Division of the IRS informed Dominion that the Joint Committee had completed its review of the settlement of tax years 2004 and 2005 for Dominion and its consolidated subsidiaries. Since the measurement of unrecognized tax benefits in 2011 considered the results of completed settlement negotiations, Dominion’s results of operations in 2012 were not affected.
In April 2012, the IRS issued its Revenue Agent Report for Dominion’s consolidated tax returns for tax years 2006 and 2007, reflecting the resolution of all issues except one that was subsequently settled in 2012.
The IRS examination of tax years 2008, 2009, 2010 and 2011 concluded in late 2013, resulting in a payment of $46 million, and an adjustment to a refund previously received by Dominion for its carryback of 2008 losses to 2007. The loss carryback, as adjusted, was submitted to the Joint Committee for review. Early in 2014, Dominion received notification that the matter had been resolved with no further adjustments. Accordingly, the earliest tax year remaining open for examination of Dominion’s federal tax returns is 2012.
Effective for its 2014 tax year, Dominion has been accepted into the CAP. The CAP is a method of identifying and resolving tax issues through open, cooperative, and transparent interaction between the IRS and taxpayers prior to the filing of a return. Through the CAP, Dominion will have the opportunity to resolve complex tax matters with the IRS before filing its federal income tax returns, thus achieving certainty for such tax return filing positions accepted by the IRS. Under a Pre-CAP plan, the IRS audit of tax years 2012 and 2013 began in early 2014.
It is reasonably possible that settlement negotiations and expiration of statutes of limitations could result in a decrease in unrecognized tax benefits in 2015 by up to $30 million for Dominion and up to $25 million for Virginia Power. If such changes were to occur, other than revisions of the accrual for interest on tax underpayments and overpayments, earnings could increase by up to $10 million for Dominion and $7 million for Virginia Power.
Otherwise, with regard to 2014 and prior years, Dominion and Virginia Power cannot estimate the range of reasonably possible changes to unrecognized tax benefits that may occur in 2015.
After considering the possibility of potential changes in the status of its remaining unrecognized tax benefits, Dominion Gas has concluded that no significant changes are reasonably possible to occur in 2015.
For each of the major states in which Dominion operates, the earliest tax year remaining open for examination is as follows:
State	Earliest Open Tax Year
Pennsylvania(1)	2010
Connecticut	2011
Virginia(2)	2011
West Virginia(1)	2011
New York(1)	2007
-1	Considered a major state for Dominion Gas' operations.
-2	Considered a major state for Virginia Power's operations.
The Companies are also obligated to report adjustments resulting from IRS settlements to state tax authorities. In addition, if Dominion utilizes operating losses or tax credits generated in years for which the statute of limitations has expired, such amounts are subject to examination.
Discontinued Operations
Details of income tax expense for Dominion's discontinued operations were as follows:
Year Ended December 31,	2013		2012
(millions)
Current:
Federal	(274	)	(248	)
State	(41	)	(6	)
Total current benefit	(315	)	(254	)
Deferred:
Federal	232		(368	)
State	40		(70	)
Total deferred expense (benefit)	272		(438	)
Total income tax benefit	(43	)	(692	)
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.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS
	Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. However, the use of a mid-market pricing convention (the mid-point between bid and ask prices) is permitted. Fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. This includes not only the credit standing of counterparties involved and the impact of credit enhancements but also the impact of the Companies' own nonperformance risk on their liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability (the market with the most volume and activity for the asset or liability from the perspective of the reporting entity), or in the absence of a principal market, the most advantageous market for the asset or liability (the market in which the reporting entity would be able to maximize the amount received or minimize the amount paid). Dominion and Virginia Power apply fair value measurements to certain assets and liabilities including commodity and interest rate derivative instruments, and nuclear decommissioning trust and other investments including those held in Dominion's rabbi, pension and other postretirement benefit plan trusts, in accordance with the requirements described above. Dominion Gas applies fair value measurements to certain assets and liabilities including commodity and interest rate derivative instruments and investments held in pension and other postretirement benefit plan trusts, in accordance with the requirements described above. The Companies apply credit adjustments to their derivative fair values in accordance with the requirements described above. These credit adjustments are currently not material to the derivative fair values.
	Inputs and Assumptions
	The Companies maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. Fair value is based on actively-quoted market prices, if available. In the absence of actively-quoted market prices, price information is sought from external sources, including broker quotes and industry publications. When evaluating pricing information provided by brokers and other pricing services, the Companies consider whether the broker is willing and able to trade at the quoted price, if the broker quotes are based on an active market or an inactive market and the extent to which brokers are utilizing a particular model if pricing is not readily available. If pricing information from external sources is not available, or if the Companies believe that observable pricing is not indicative of fair value, judgment is required to develop the estimates of fair value. In those cases the Companies must estimate prices based on available historical and near-term future price information and certain statistical methods, including regression analysis, that reflect their market assumptions.
	The Companies' commodity derivative valuations are prepared by Dominion's ERM department. The ERM department reports directly to Dominion's CFO. The ERM department creates daily mark-to-market valuations for the Companies' derivative transactions using computer-based statistical models. The inputs that go into the market valuations are transactional information stored in the systems of record and market pricing information that resides in data warehouse databases. The majority of forward prices are automatically uploaded into the data warehouse databases from various third-party sources. Inputs obtained from third-party sources are evaluated for reliability considering the reputation, independence, market presence, and methodology used by the third-party. If forward prices are not available from third-party sources, then the ERM department models the forward prices based on other available market data. A team consisting of risk management and risk quantitative analysts meets each business day to assess the validity of market prices and mark-to-market valuations. During this meeting, the changes in mark-to-market valuations from period to period are examined and qualified against historical expectations. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	For options and contracts with option-like characteristics where observable pricing information is not available from external sources, Dominion and Virginia Power generally use a modified Black-Scholes Model that considers time value, the volatility of the underlying commodities and other relevant assumptions when estimating fair value. Dominion and Virginia Power use other option models under special circumstances, including a Spread Approximation Model when contracts include different commodities or commodity locations and a Swing Option Model when contracts allow either the buyer or seller the ability to exercise within a range of quantities. For contracts with unique characteristics, Dominion and Virginia Power may estimate fair value using a discounted cash flow approach deemed appropriate in the circumstances and applied consistently from period to period. For individual contracts, the use of different valuation models or assumptions could have a significant effect on the contract's estimated fair value.
	The inputs and assumptions used in measuring fair value include the following:
	For commodity and foreign currency derivative contracts:
	•	Forward commodity prices
	•	Forward foreign currency prices
	•	Transaction prices
	•	Price volatility
	•	Price correlation
	•	Volumes
	•	Commodity location
	•	Interest rates
	•	Credit quality of counterparties and the Companies
	•	Credit enhancements
	•	Time value
	For interest rate derivative contracts:
	•	Interest rate curves
	•	Credit quality of counterparties and the Companies
	•	Volumes
	•	Credit enhancements
	•	Time value
	For investments:
	•	Quoted securities prices and indices
	•	Securities trading information including volume and restrictions
	•	Maturity
	•	Interest rates
	•	Credit quality
	•	NAV (for alternative investments and common/collective trust funds)
	The Companies regularly evaluate and validate the inputs used to estimate fair value by a number of methods, including review and verification of models, as well as various market price verification procedures such as the use of pricing services and multiple broker quotes to support the market price of the various commodities and investments in which the Companies transact.
	Levels
	The Companies also utilize the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:
	•Level 1-Quoted prices (unadjusted) in active markets for identical assets and liabilities that they have the ability to access at the measurement date. Instruments categorized in Level 1 primarily consist of financial instruments such as certain exchange-traded derivatives, and exchange-listed equities, mutual funds and certain Treasury securities held in nuclear decommissioning trust funds for Dominion and Virginia Power, benefit plan trust funds for Dominion and Dominion Gas, and rabbi trust funds for Dominion.
	•Level 2-Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 primarily include commodity forwards and swaps, interest rate swaps, restricted cash equivalents, and certain Treasury securities, money market funds, common/collective trust funds, and corporate, state and municipal debt securities held in nuclear decommissioning trust funds for Dominion and Virginia Power, benefit plan trust funds for Dominion and Dominion Gas, and rabbi trust funds for Dominion.
	•Level 3-Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity for the asset or liability. Instruments categorized in Level 3 for the Companies consist of long-dated commodity derivatives, FTRs, NGLs, natural gas peaking options and other modeled commodity derivatives. Additional instruments categorized in Level 3 for Dominion and Dominion Gas include alternative investments, consisting of investments in partnerships, joint ventures and other alternative investments, held in benefit plan trust funds.
	The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability.
	For derivative contracts, the Companies recognize transfers among Level 1, Level 2 and Level 3 based on fair values as of the first day of the month in which the transfer occurs. Transfers out of Level 3 represent assets and liabilities that were previously classified as Level 3 for which the inputs became observable for classification in either Level 1 or Level 2. Because the activity and liquidity of commodity markets vary substantially between regions and time periods, the availability of observable inputs for substantially the full term and value of the Companies' over-the-counter derivative contracts is subject to change.
	Level 3 Valuations
	Fair value measurements are categorized as Level 3 when a significant amount of price or other inputs that are considered to be unobservable are used in their valuations. Long-dated commodity derivatives are generally based on unobservable inputs due to the length of time to settlement and the absence of market activity and are therefore categorized as Level 3. For NGL derivatives, market illiquidity requires a valuation based on proxy markets that do not always correlate to the actual instrument, therefore they are categorized as Level 3. FTRs are categorized as Level 3 fair value measurements because the only relevant pricing available comes from ISO auctions, which are generally not considered to be liquid markets. Other modeled commodity derivatives have unobservable inputs in their valuation, mostly due to non-transparent and illiquid markets. Alternative investments are categorized as Level 3 due to the absence of quoted market prices, illiquidity and the long-term nature of these assets. These investments are generally valued using NAV based on the proportionate share of the fair value as determined by reference to the most recent audited fair value financial statements or fair value statements provided by the investment manager adjusted for any significant events occurring between the investment manager's and the Companies' measurement date.
	The Companies enter into certain physical and financial forwards, futures, options and swaps, 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 and futures 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. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, the original sales prices, and volumes. For Level 3 fair value measurements, forward market prices, credit spreads and implied price volatilities 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 Dominion Gas' quantitative information about Level 3 fair value measurements at December 31, 2014. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility and credit spreads.
		Fair Value (millions)			Valuation Techniques	Unobservable Input		Range		Weighted Average(1)
	Assets:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	74		Discounted Cash Flow	Market Price (per Dth)	(4)	(2) - 11		(1	)
						Credit spread	(6)	1% - 5%		2	%
	FTRs	44			Discounted Cash Flow	Market Price (per MWh)	(4)	(1) - 21		3
	NGLs(3)	2			Discounted Cash Flow	Market Price (per Gal)	(4)	0 - 2		1
	Physical and Financial Options:
	Natural Gas	5			Option Model	Market Price (per Dth)	(4)	4-Feb		3
						Price Volatility	(5)	19% - 67%		33	%
	Total assets	$	125
	Liabilities:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	12		Discounted Cash Flow	Market Price (per Dth)	(4)	(2) - 4		2
	FTRs	4			Discounted Cash Flow	Market Price (per MWh)	(4)	(21) - 21		—
	Physical and Financial Options:
	Natural Gas	2			Option Model	Market Price (per Dth)	(4)	4-Feb		3
						Price Volatility	(5)	19% - 67%		33	%
	Total liabilities	$	18
	-1	Averages weighted by volume.
-2	Includes basis.
-3	Information represents Dominion Gas quantitative information about Level 3 fair value measurements.
-4	Represents market prices beyond defined terms for Levels 1 and 2.
-5	Represents volatilities unrepresented in published markets.
-6	Represents credit spreads unrepresented in published markets.
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)
Credit spread	Asset	Increase (decrease)	Loss (gain)
Nonrecurring Fair Value Measurements
Dominion Gas
Natural Gas Assets
In the fourth quarter of 2014, Dominion Gas recorded an impairment charge of $9 million ($6 million after-tax) in other operations and maintenance expense in its Consolidated Statements of Income, to write off previously capitalized costs following the cancellation of a development project.
In June 2013, Dominion Gas 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 Gas 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 Gas 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.
Also in June 2013, Dominion Gas recorded an impairment charge of $6 million ($4 million after-tax) in other operations and maintenance expense in its Consolidated Statements of Income, to write off previously capitalized costs following the cancellation of two development projects.
Dominion
Merchant Power Stations
In the third quarter of 2012, Dominion decided to pursue the sale of Brayton Point and Kincaid, as well as its 50% interest in Elwood, which is an equity method investment. Since Dominion was unlikely to operate the Brayton Point and Kincaid facilities through their estimated useful lives, Dominion evaluated these power stations for recoverability under a probability weighted approach and concluded that the carrying values of these facilities were not impaired as of September 30, 2012.
At December 31, 2012, Dominion updated its recoverability analysis for Brayton Point and Kincaid to reflect bids received and an updated probability weighting. As a result of this updated evaluation, Dominion recorded an impairment charge of approximately $1.6 billion ($1.0 billion after-tax), which is included in loss from discontinued operations in its Consolidated Statement of Income, to write down Brayton Point’s and Kincaid's long-lived assets to their estimated fair value of approximately $216 million. Dominion used a market approach to estimate the fair value of Brayton Point’s and Kincaid's long-lived assets. This was considered a Level 2 fair value measurement given it was based on bids received.
See Note 3 for information regarding the sale of Brayton Point, Kincaid and Dominion's equity method investment in Elwood, including an additional impairment.
In April 2011, Dominion announced it would pursue a sale of Kewaunee since it was not able to move forward with its original plan to grow its nuclear fleet in the Midwest to take advantage of economies of scale. Dominion was unable to find a buyer for the facility. In addition, the power purchase agreements for the two utilities that contracted to buy Kewaunee's generation expired in December 2013 at a time of low wholesale electricity prices in the region. At September 30, 2012, Dominion expected that it would permanently cease generation operations at Kewaunee in 2013 and commence decommissioning of the facility. As a result, Dominion evaluated Kewaunee for impairment since it was more likely than not that Kewaunee would be retired before the end of its previously estimated useful life. 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 Kewaunee's long-lived assets. This was considered a Level 3 fair value measurement due to the use of significant unobservable inputs including estimates of future power and other commodity prices.
As a result of this evaluation in September 2012, Dominion recorded impairment and other charges of $435 million ($281 million after-tax) largely reflected in other operations and maintenance expense in its Consolidated Statement of Income. This primarily reflects a $378 million ($244 million after-tax) charge for the full impairment of Kewaunee's long-lived assets, a write down of materials and supplies inventories of $33 million ($21 million after-tax), and a $24 million ($16 million after-tax) charge related to severance costs.
The decision to decommission Kewaunee was approved by Dominion's Board of Directors in October 2012 after consideration of the factors discussed above, which made it uneconomic for Kewaunee to continue operations. Kewaunee ceased operations and decommissioning activities commenced in May 2013.
In the second quarter of 2012, an agreement was reached to sell Salem Harbor and the assets and liabilities to be disposed were classified as held for sale and adjusted to their estimated fair value less cost to sell. This resulted in a pre-tax charge of $27 million ($16 million after-tax), which is included in loss from discontinued operations in Dominion's Consolidated Statement of Income. This was considered a Level 2 fair value measurement as it was based on the negotiated sales price. Salem Harbor was sold in the third quarter of 2012.
Recurring Fair Value Measurements
Fair value measurements are separately disclosed by level within the fair value hierarchy with a separate reconciliation of fair value measurements categorized as Level 3. Fair value disclosures for assets held in Dominion's and Dominion Gas' pension and other postretirement benefit plans are presented in Note 21.
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 December 31, 2014
Assets:
Derivatives:
Commodity	$	3		$	567		$	125		$	695
Interest rate	—			24			—			24
Investments(1):
Equity securities:
U.S.:
Large Cap	2,669			—			—			2,669
Other	6			—			—			6
Non-U.S.:
Large Cap	12			—			—			12
Fixed Income:
Corporate debt instruments	—			441			—			441
U.S. Treasury securities and agency debentures	419			190			—			609
State and municipal	—			395			—			395
Other	—			74			—			74
Cash equivalents and other	3			10			—			13
Total assets	$	3,112		$	1,701		$	125		$	4,938
Liabilities:
Derivatives:
Commodity	$	3		$	571		$	18		$	592
Interest rate	—			202			—			202
Total liabilities	$	3		$	773		$	18		$	794
At December 31, 2013
Assets:
Derivatives:
Commodity	$	3		$	718		$	32		$	753
Interest rate	—			137			—			137
Investments(1):
Equity securities:
U.S.:
Large Cap	2,417			—			—			2,417
Other	79			—			—			79
Non-U.S.:
Large Cap	13			—			—			13
Fixed Income:
Corporate debt instruments	—			345			—			345
U.S. Treasury securities and agency debentures	415			175			—			590
State and municipal	—			343			—			343
Other	—			3			—			3
Cash equivalents and other	—			103			—			103
Restricted cash equivalents	—			8			—			8
Total assets	$	2,927		$	1,832		$	32		$	4,791
Liabilities:
Derivatives:
Commodity	$	3		$	1,051		$	48		$	1,102
Total liabilities	$	3		$	1,051		$	48		$	1,102
-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:
	2014			2013			2012
(millions)
Balance at January 1,	$	(16	)	$	25		$	(71	)
Total realized and unrealized gains (losses):
Included in earnings	97			(9		)	(15		)
Included in other comprehensive income (loss)	7			1			101
Included in regulatory assets/liabilities	109			(9		)	30
Settlements	(88		)	(23		)	47
Transfers out of Level 3	(2		)	(1		)	(67		)
Balance at December 31,	$	107		$	(16	)	$	25
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	$	6		$	—		$	42
The following table presents Dominion's gains and losses included in earnings in the Level 3 fair value category:
	Operating			Electric Fuel			Purchased			Total
	Revenue			and Energy			Gas
				Purchases
(millions)
Year Ended December 31, 2014
Total gains (losses) included in earnings	$	4		$	97		$	(4	)	$	97
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	4			1			1			6
Year Ended December 31, 2013
Total gains (losses) included in earnings	$	11		$	(19	)	$	(1	)	$	(9	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	1			—			(1		)	—
Year Ended December 31, 2012
Total gains (losses) included in earnings	$	35		$	(50	)	$	—		$	(15	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	42			—			—			42
Virginia Power
The following table presents Virginia Power's quantitative information about Level 3 fair value measurements at December 31, 2014. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads.
	Fair Value (millions)			Valuation Techniques	Unobservable Input		Range		Weighted Average(1)
Assets:
Physical and Financial Forwards and Futures:
FTRs	$	44		Discounted Cash Flow	Market Price (per MWh)	(3)	(1) - 21		3
Natural gas(2)	62			Discounted Cash Flow	Market Price (per Dth)	(3)	(2) - 7		(1	)
					Credit spread	(4)	1% - 5%		2	%
Total assets	$	106
Liabilities:
Physical and Financial Forwards and Futures:
FTRs	$	4		Discounted Cash Flow	Market Price (per MWh)	(3)	(21) - 21		—
Total liabilities	$	4
-1	Averages weighted by volume.
-2	Includes basis.
-3	Represents market prices beyond defined terms for Levels 1 and 2.
-4	Represents credit spreads unrepresented in published markets.
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)
Credit spread	Asset	Increase (decrease)	Loss (gain)
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 December 31, 2014
Assets:
Derivatives:
Commodity	$	—		$	7		$	106		$	113
Investments(1):
Equity securities:
U.S.:
Large Cap	1,157			—			—			1,157
Fixed Income:
Corporate debt instruments	—			250			—			250
U.S. Treasury securities and agency debentures	137			61			—			198
State and municipal	—			211			—			211
Other	—			23			—			23
Total assets	$	1,294		$	552		$	106		$	1,952
Liabilities:
Derivatives:
Commodity	$	—		$	11		$	4		$	15
Interest rate	—			72			—			72
Total liabilities	$	—		$	83		$	4		$	87
At December 31, 2013
Assets:
Derivatives:
Commodity	$	—		$	3		$	2		$	5
Interest rate	—			48			—			48
Investments(1):
Equity securities:
U.S.:
Large Cap	1,021			—			—			1,021
Other	36			—			—			36
Fixed Income:
Corporate debt instruments	—			191			—			191
U.S. Treasury securities and agency debentures	146			66			—			212
State and municipal	—			164			—			164
Cash equivalents and other	—			31			—			31
Restricted cash equivalents	—			8			—			8
Total assets	$	1,203		$	511		$	2		$	1,716
Liabilities:
Derivatives:
Commodity	$	—		$	3		$	9		$	12
Total liabilities	$	—		$	3		$	9		$	12
-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:
	2014			2013			2012
(millions)
Balance at January 1,	$	(7	)	$	2		$	(28	)
Total realized and unrealized gains (losses):
Included in earnings	96			(17		)	(50		)
Included in regulatory assets/liabilities	109			(9		)	30
Settlements	(96		)	17			50
Balance at December 31,	$	102		$	(7	)	$	2
The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases expense in Virginia Power's Consolidated Statements of Income for the years ended December 31, 2014, 2013 and 2012. There were no unrealized gains and losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the years ended December 31, 2014, 2013 and 2012.
Dominion Gas
The following table presents Dominion Gas' assets and liabilities for commodity and interest rate derivatives 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 December 31, 2014
Assets:
Commodity	$	—		$	—		$	2		$	2
Total assets	$	—		$	—		$	2		$	2
Liabilities:
Interest rate	$	—		$	9		$	—		$	9
Total liabilities	$	—		$	9		$	—		$	9
At December 31, 2013
Assets:
Commodity	$	—		$	—		$	6		$	6
Interest rate	—			34			—			34
Total assets	$	—		$	34		$	6		$	40
Liabilities:
Commodity	$	—		$	13		$	12		$	25
Total liabilities	$	—		$	13		$	12		$	25
The following table presents the net change in Dominion Gas' derivative assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:
	2014			2013			2012
(millions)
Balance at January 1,	$	(6	)	$	(12	)	$	(98	)
Total realized and unrealized gains (losses):
Included in earnings	2			1			(15		)
Included in other comprehensive income (loss)	10			3			86
Settlements	(4		)	2			15
Balance at December 31,	$	2		$	(6	)	$	(12	)
The gains and losses included in earnings in the Level 3 fair value category were classified in operating revenue in Dominion Gas' Consolidated Statements of Income for the years ended December 31, 2014, 2013 and 2012. There were no unrealized gains and losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the years ended December 31, 2014, 2013 and 2012.
Fair Value of Financial Instruments
Substantially all of the Companies' 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, restricted cash (which is recorded in other current assets), customer and other receivables, short-term debt, affiliated current borrowings, payables to affiliates and accounts payable are representative of fair value because of the short-term nature of these instruments. For the Companies' financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows:
At December 31,	2014						2013
	Carrying			Estimated			Carrying			Estimated
	Amount			Fair Value(1)			Amount			Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	19,723		$	21,881		$	18,396		$	19,887
Junior subordinated notes(3)	1,374			1,396			1,373			1,394
Remarketable subordinated notes(3)	2,083			2,362			1,080			1,192
Subsidiary preferred stock(4)	—			—			257			261
Virginia Power
Long-term debt, including securities due within one year(3)	$	8,937		$	10,293		$	8,032		$	8,897
Preferred stock(4)	—			—			257			261
Dominion Gas
Long-term debt(3)	$	2,594		$	2,672		$	1,198		$	1,169
-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/or premium. At December 31, 2014, and 2013, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of approximately $19 million and $55 million, respectively.
-3	Carrying amount includes amounts which represent the unamortized discount and/or premium.
-4	Includes deferred issuance expenses of $2 million at December 31, 2013. See Note 18 for information about the redemption of preferred stock in 2014.

Derivatives_and_Hedge_Accounti

Derivatives and Hedge Accounting Activities	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives and Hedge Accounting Activities	DERIVATIVES AND HEDGE ACCOUNTING ACTIVITIES
	The Companies are exposed to the impact of market fluctuations in the price of electricity, natural gas and other energy-related products they market and purchase, as well as currency exchange and interest rate risks of their business operations. The Companies use derivative instruments to manage exposure to these risks, and designate certain derivative instruments as fair value or cash flow hedges for accounting purposes. As discussed in Note 2, for jurisdictions subject to cost-based rate regulation, changes in the fair value of derivatives are deferred as regulatory assets or regulatory liabilities until the related transactions impact earnings. See Note 6 for further information about fair value measurements and associated valuation methods for derivatives.
	Derivative assets and liabilities are presented gross on the Companies' 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. Dominion Gas' derivative contracts include over-the-counter transactions. 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 the Companies' 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
	Balance Sheet Presentation
	The tables below present Dominion's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
		31-Dec-14									31-Dec-13
		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	$	24		$	—		$	24		$	137	$	—	$	137
	Commodity contracts:
	Over-the-counter	382			—			382			240		—		240
	Exchange	298			—			298			506		—		506
	Total derivatives, subject to a master netting or similar arrangement	704			—			704			883		—		883
	Total derivatives, not subject to a master netting or similar arrangement	15			—			15			7		—		7
	Total	$	719		$	—		$	719		$	890	$	—	$	890
					31-Dec-14										31-Dec-13
					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	$	24		$	16		$	—		$	8	$	137	$	—	$	—	$	137
	Commodity contracts:
	Over-the-counter	382			34			34			314		240		63		—		177
	Exchange	298			298			—			—		506		505		—		1
	Total	$	704		$	348		$	34		$	322	$	883	$	568	$	—	$	315
		31-Dec-14									31-Dec-13
		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	$	202		$	—		$	202		$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	87			—			87			262		—		262
	Exchange	493			—			493			838		—		838
	Total derivatives, subject to a master netting or similar arrangement	782			—			782			1,100		—		1,100
	Total derivatives, not subject to a master netting or similar arrangement	12			—			12			2		—		2
	Total	$	794		$	—		$	794		$	1,102	$	—	$	1,102
					31-Dec-14										31-Dec-13
					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	$	202		$	16		$	—		$	186	$	—	$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	87			34			1			52		262		63		69		130
	Exchange	493			298			195			—		838		505		333		—
	Total	$	782		$	348		$	196		$	238	$	1,100	$	568	$	402	$	130
	Volumes
	The following table presents the volume of Dominion's derivative activity as of December 31, 2014. 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)	52			13
	Basis	227			575
	Electricity (MWh):
	Fixed price	14,689,432			6,148,800
	FTRs	35,786,150			—
	Capacity (MW)	10,700			7,600
	Liquids (Gals)(2)	39,984,000			1,260,000
	Interest rate	$	1,300,000,000		$	4,450,000,000
	-1	Includes options.
	-2	Includes NGLs and oil.
	Ineffectiveness and AOCI
For the years ended December 31, 2014, 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 December 31, 2014:
	AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum
	After-Tax						Term
(millions)
Commodities:
Gas	$	(8	)	$	(7	)	27 months
Electricity	56			46			24 months
Other	—			—			17 months
Interest rate	(226		)	(6		)	384 months
Total	$	(178	)	$	33
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 tables present the fair values of Dominion's derivatives and where they are presented in its Consolidated Balance Sheets:
	Fair Value  -			Fair Value -			Total
	Derivatives			Derivatives			Fair
	under			not under			Value
	Hedge			Hedge
	Accounting			Accounting
(millions)
At December 31, 2014
ASSETS
Current Assets
Commodity	$	281		$	242		$	523
Interest rate	13			—			13
Total current derivative assets	294			242			536
Noncurrent Assets
Commodity	71			101			172
Interest rate	11			—			11
Total noncurrent derivative assets(1)	82			101			183
Total derivative assets	$	376		$	343		$	719
LIABILITIES
Current Liabilities
Commodity	$	224		$	267		$	491
Interest rate	100			—			100
Total current derivative liabilities	324			267			591
Noncurrent Liabilities
Commodity	55			46			101
Interest rate	102			—			102
Total noncurrent derivative liabilities(2)	157			46			203
Total derivative liabilities	$	481		$	313		$	794
At December 31, 2013
ASSETS
Current Assets
Commodity	$	49		$	522		$	571
Interest rate	116			—			116
Total current derivative assets	165			522			687
Noncurrent Assets
Commodity	28			154			182
Interest rate	21			—			21
Total noncurrent derivative assets(1)	49			154			203
Total derivative assets	$	214		$	676		$	890
LIABILITIES
Current Liabilities
Commodity	$	267		$	561		$	828
Total current derivative liabilities	267			561			828
Noncurrent Liabilities
Commodity	119			155			274
Total noncurrent derivative liabilities(2)	119			155			274
Total derivative liabilities	$	386		$	716		$	1,102
-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	Amount of			Amount of			Increase
relationships	Gain (Loss)			Gain (Loss)			(Decrease)
	Recognized			Reclassified			in
	in AOCI on			from AOCI			Derivatives
	Derivatives			to Income			Subject to
	(Effective						Regulatory
	Portion)(1)						Treatment(2)
(millions)
Year Ended December 31, 2014
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	(130	)
Purchased gas				(13		)
Electric fuel and other energy-related purchases				7
Total commodity	$	245		$	(136	)	$	(4	)
Interest rate(3)	(208		)	(16		)	(81		)
Total	$	37		$	(152	)	$	(85	)
Year Ended December 31, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	(58	)
Purchased gas				(47		)
Electric fuel and other energy-related purchases				(10		)
Total commodity	$	(481	)	$	(115	)	$	5
Interest rate(3)	77			(15		)	81
Total	$	(404	)	$	(130	)	$	86
Year Ended December 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	188
Purchased gas				(75		)
Electric fuel and other energy-related purchases				(17		)
Total commodity	$	71		$	96		$	10
Interest rate(3)	(84		)	(2		)	(35		)
Total	$	(13	)	$	94		$	(25	)
-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.
Derivatives not designated as hedging	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
instruments
Year Ended December 31,	2014			2013			2012
(millions)
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue	$	(310	)	$	(45	)	$	168
Purchased gas	(51		)	(9		)	(14		)
Electric fuel and other energy-related purchases	113			(29		)	(40		)
Interest rate(2)	—			—			17
Total	$	(248	)	$	(83	)	$	131
-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
Balance Sheet Presentation
The tables below present Virginia Power's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
	31-Dec-14									31-Dec-13
	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	$	—		$	—		$	—		$	48	$	—	$	48
Commodity contracts:
Over-the-counter	106			—			106			4		—		4
Exchange	—			—			—			1		—		1
Total derivatives, subject to a master netting or similar arrangement	106			—			106			53		—		53
Total derivatives, not subject to a master netting or similar arrangement	7			—			7			—		—		—
Total	$	113		$	—		$	113		$	53	$	—	$	53
				31-Dec-14										31-Dec-13
				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	$	—		$	—		$	—		$	—	$	48	$	—	$	—	$	48
Commodity contracts:
Over-the-counter	106			4			—			102		4		4		—		—
Exchange	—			—			—			—		1		—		—		1
Total	$	106		$	4		$	—		$	102	$	53	$	4	$	—	$	49
	31-Dec-14									31-Dec-13
	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	$	72		$	—		$	72		$	—	$	—	$	—
Commodity contracts:
Over-the-counter	8			—			8			12		—		12
Total derivatives, subject to a master netting or similar arrangement	80			—			80			12		—		12
Total derivatives, not subject to a master netting or similar arrangement	7			—			7			—		—		—
Total	$	87		$	—		$	87		$	12	$	—	$	12
				31-Dec-14										31-Dec-13
				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	$	72		$	—		$	—		$	72	$	—	$	—	$	—	$	—
Commodity contracts:
Over-the-counter	8			4			—			4		12		4		7		1
Total	$	80		$	4		$	—		$	76	$	12	$	4	$	7	$	1
Volumes
The following table presents the volume of Virginia Power's derivative activity at December 31, 2014. 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	7			—
Basis	51			493
Electricity (MWh):
FTRs	33,709,386			—
Capacity (MW)	10,700			7,600
Interest rate	$	550,000,000		$	900,000,000
Ineffectiveness
For the years ended December 31, 2014, 2013 and 2012, gains or losses on hedging instruments determined to be ineffective were not material.
Fair Value and Gains and Losses on Derivative Instruments
The following tables present the fair values of Virginia Power's derivatives and where they are presented in its Consolidated Balance Sheets:
	Fair Value  -			Fair Value -			Total
	Derivatives			Derivatives			Fair
	under			not under			Value
	Hedge			Hedge
	Accounting			Accounting
(millions)
At December 31, 2014
ASSETS
Current Assets
Commodity	$	—		$	51		$	51
Total current derivative assets(1)	—			51			51
Noncurrent Assets
Commodity	—			62			62
Total noncurrent derivative assets(2)	—			62			62
Total derivative assets	$	—		$	113		$	113
LIABILITIES
Current Liabilities
Commodity	$	3		$	12		$	15
Interest rate	45			—			45
Total current derivative liabilities	48			12			60
Noncurrent Liabilities
Interest rate	27			—			27
Total noncurrent derivative liabilities(3)	27			—			27
Total derivative liabilities	$	75		$	12		$	87
At December 31, 2013
ASSETS
Current Assets
Commodity	$	2		$	3		$	5
Interest rate	48			—			48
Total current derivative assets(1)	50			3			53
Total derivative assets	$	50		$	3		$	53
LIABILITIES
Current Liabilities
Commodity	$	1		$	11		$	12
Total current derivative liabilities	1			11			12
Total derivative liabilities	$	1		$	11		$	12
-1	Current derivative assets are presented in other current assets in Virginia Power's Consolidated Balance Sheets.
-2	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power's Consolidated Balance Sheets.
-3	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	Amount of Gain			Amount of			Increase
relationships	(Loss)			Gain (Loss)			(Decrease) in
	Recognized in			Reclassified			Derivatives
	AOCI on			from AOCI to			Subject to
	Derivatives			Income			Regulatory
	(Effective						Treatment(2)
	Portion)(1)
(millions)
Year Ended December 31, 2014
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	5
Total commodity	$	4		$	5		$	(4	)
Interest rate(3)	(10		)	—			(81		)
Total	$	(6	)	$	5		$	(85	)
Year Ended December 31, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	—
Total commodity	$	—		$	—		$	5
Interest rate(3)	9			—			81
Total	$	9		$	—		$	86
Year Ended December 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(4	)
Total commodity	$	(2	)	$	(4	)	$	10
Interest rate(3)	(6		)	—			(35		)
Total	$	(8	)	$	(4	)	$	(25	)
-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.
Derivatives not designated as hedging	Amount of Gain (Loss) Recognized
instruments	in Income on Derivatives(1)
Year Ended December 31,	2014			2013			2012
(millions)
Derivative Type and Location of Gains (Losses)
Commodity(2)	$	105		$	(16	)	$	(50	)
Total	$	105		$	(16	)	$	(50	)
-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.
Dominion Gas
Balance Sheet Presentation
The tables below present Dominion Gas' derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
	31-Dec-14									31-Dec-13
	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	$	—		$	—		$	—		$	34	$	—	$	34
Commodity contracts:
Over-the-counter	2			—			2			6		—		6
Total derivatives, subject to a master netting or similar arrangement	$	2		$	—		$	2		$	40	$	—	$	40
				31-Dec-14										31-Dec-13
				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	$	—		$	—		$	—		$	—	$	34	$	—	$	—	$	34
Commodity contracts:
Over-the-counter	2			—			—			2		6		6		—		—
Total	$	2		$	—		$	—		$	2	$	40	$	6	$	—	$	34
	31-Dec-14									31-Dec-13
	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	$	9		$	—		$	9		$	—	$	—	$	—
Commodity contracts:
Over-the-counter	—			—			—			25		—		25
Total derivatives, subject to a master netting or similar arrangement	$	9		$	—		$	9		$	25	$	—	$	25
				31-Dec-14										31-Dec-13
				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	$	9		$	—		$	—		$	9	$	—	$	—	$	—	$	—
Commodity contracts:
Over-the-counter	—			—			—			—		25		6		—		19
Total	$	9		$	—		$	—		$	9	$	25	$	6	$	—	$	19
Volumes
The following table presents the volume of Dominion Gas' derivative activity at December 31, 2014. 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
NGLs	32,340,000			—
Interest rate	$	—		$	250,000,000
Ineffectiveness and AOCI
For the years ended December 31, 2014, 2013 and 2012, gains or losses on hedging instruments determined to be ineffective were not material.
The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion Gas' Consolidated Balance Sheet at December 31, 2014:
	AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum
	After-Tax						Term
(millions)
Commodities:
Natural Gas	$	—		$	—		3 months
NGLs	—			—			12 months
Interest rate	(20		)	—			360 months
Total	$	(20	)	$	—
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 tables present the fair values of Dominion Gas' derivatives and where they are presented in its Consolidated Balance Sheets:
	Fair Value  -			Fair Value -			Total
	Derivatives			Derivatives			Fair
	under			not under			Value
	Hedge			Hedge
	Accounting			Accounting
(millions)
At December 31, 2014
ASSETS
Current Assets
Commodity	$	2		$	—		$	2
Total current derivative assets(1)	2			—			2
Total derivative assets	$	2		$	—		$	2
LIABILITIES
Noncurrent Liabilities
Interest rate	$	9		$	—		$	9
Total noncurrent derivative liabilities(2)	9			—			9
Total derivative liabilities	$	9		$	—		$	9
At December 31, 2013
ASSETS
Current Assets
Commodity	$	6		$	—		$	6
Interest rate	34			—			34
Total current derivative assets(1)	40			—			40
Total derivative assets	$	40		$	—		$	40
LIABILITIES
Current Liabilities
Commodity	$	25		$	—		$	25
Total current derivative liabilities(3)	25			—			25
Total derivative liabilities	$	25		$	—		$	25
-1	Current derivative assets are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.
-2	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.
-3	Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.
The following tables present the gains and losses on Dominion Gas' derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:
Derivatives in cash flow hedging	Amount of Gain			Amount of
relationships	(Loss)			Gain (Loss)
	Recognized in			Reclassified
	AOCI on			from AOCI to
	Derivatives			Income
	(Effective
	Portion)(1)
(millions)
Year Ended December 31, 2014
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	2
Purchased gas				(14		)
Total commodity	$	12		$	(12	)
Interest rate(2)	(62		)	(1		)
Total	$	(50	)	$	(13	)
Year Ended December 31, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	(2	)
Purchased gas				(14		)
Total commodity	$	(2	)	$	(16	)
Interest rate(2)	68			—
Total	$	66		$	(16	)
Year Ended December 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	(15	)
Purchased gas				(18		)
Total commodity	$	64		$	(33	)
Interest rate(2)	(41		)	—
Total	$	23		$	(33	)
-1	Amounts deferred into AOCI have no associated effect in Dominion Gas' Consolidated Statements of Income.
-2	Amounts recorded in Dominion Gas' Consolidated Statements of Income are classified in interest and related charges.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share	EARNINGS PER SHARE
	The following table presents the calculation of Dominion's basic and diluted EPS:
		2014		2013		2012
	(millions, except EPS)
	Net income attributable to Dominion	$	1,310	$	1,697	$	302
	Average shares of common stock outstanding-Basic	582.7		578.7		572.9
	Net effect of dilutive securities(1)	1.8		0.8		1
	Average shares of common stock outstanding-Diluted	584.5		579.5		573.9
	Earnings Per Common Share-Basic	$	2.25	$	2.93	$	0.53
	Earnings Per Common Share-Diluted	$	2.24	$	2.93	$	0.53
	-1	Dilutive securities consist primarily of contingently convertible senior notes and the 2013 Equity Units for 2014 and contingently convertible senior notes for 2013 and 2012. Dominion redeemed all of its contingently convertible senior notes in 2014. See Note 17 for more information.
	The 2014 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the year ended December 31, 2014, as the dilutive stock price threshold was not met. The 2013 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the year ended December 31, 2013. See Note 17 for more information. There were no potentially dilutive securities excluded from the calculation of diluted EPS for the year ended December 31, 2012.

Investments

Investments	12 Months Ended
	Dec. 31, 2014
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 $110 million and $107 million at December 31, 2014 and 2013, respectively. Cost-method investments held in Dominion's rabbi trusts totaled $6 million and $10 million at December 31, 2014 and 2013, 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			Total				Fair
		Cost			Unrealized			Unrealized				Value
					Gains (1)			Losses (1)
	(millions)
	2014
	Marketable equity securities:
	U.S. large cap	$	1,273		$	1,353		$	—			$	2,626
	Marketable debt securities:
	Corporate debt instruments	424			19			(2		)		441
	U.S. Treasury securities and agency debentures	597			13			(4		)		606
	State and municipal	332			23			—				355
	Other	66			—			—				66
	Cost method investments	86			—			—				86
	Cash equivalents and other(2)	16			—			—				16
	Total	$	2,794		$	1,408		$	(6	)	(3)	$	4,196
	2013
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,183		$	1,194		$	—			$	2,377
	Other	49			23			—				72
	Marketable debt securities:
	Corporate debt instruments	332			16			(3		)		345
	U.S. Treasury securities and agency debentures	589			8			(10		)		587
	State and municipal	297			11			(5		)		303
	Other	3			—			—				3
	Cost method investments	106			—			—				106
	Cash equivalents and other(2)	110			—			—				110
	Total	$	2,669		$	1,252		$	(18	)	(3)	$	3,903
	-1	Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
	-2	Includes pending sales of securities of $3 million and $11 million at December 31, 2014 and 2013, respectively.
	-3	The fair value of securities in an unrealized loss position was $379 million and $604 million at December 31, 2014 and 2013, respectively.
	The fair value of Dominion's marketable debt securities held in nuclear decommissioning trust funds at December 31, 2014 by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	169
	Due after one year through five years	390
	Due after five years through ten years	426
	Due after ten years	483
	Total	$	1,468
	Presented below is selected information regarding Dominion's marketable equity and debt securities held in nuclear decommissioning trust funds:
	Year Ended December 31,	2014			2013			2012
	(millions)
	Proceeds from sales	$	1,235		$	1,476		$	1,356
	Realized gains(1)	171			157			98
	Realized losses(1)	30			33			33
	-1	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
	Dominion recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows:
	Year Ended December 31,	2014			2013			2012
	(millions)
	Total other-than-temporary impairment losses(1)	$	21		$	31		$	26
	Losses recorded to decommissioning trust regulatory liability	(5		)	(13		)	(10		)
	Losses recognized in other comprehensive income (before taxes)	(3		)	(10		)	(2		)
	Net impairment losses recognized in earnings	$	13		$	8		$	14
	-1	Amounts include other-than-temporary impairment losses for debt securities of $3 million, $18 million and $4 million at December 31, 2014, 2013 and 2012, respectively.
	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			Total				Fair
Cost		Unrealized			Unrealized			Value
		Gains (1)			Losses (1)
(millions)
2014
Marketable equity securities:
U.S. large cap	$	563		$	594		$	—			$	1,157
Marketable debt securities:
Corporate debt instruments	242			9			(1		)		250
U.S. Treasury securities and agency debentures	197			3			(2		)		198
State and municipal	197			13			—				210
Other	23			—			—				23
Cost method investments	86			—			—				86
Cash equivalents and other(2)	6			—			—				6
Total	$	1,314		$	619		$	(3	)	(3)	$	1,930
2013
Marketable equity securities:
U.S.:
Large Cap	$	506		$	514		$	—			$	1,020
Other	25			11			—				36
Marketable debt securities:
Corporate debt instruments	185			8			(2		)		191
U.S. Treasury securities and agency debentures	214			1			(3		)		212
State and municipal	163			4			(4		)		163
Cost method investments	106			—			—				106
Cash equivalents and other(2)	37			—			—				37
Total	$	1,236		$	538		$	(9	)	(3)	$	1,765
-1	Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
-2	Includes pending sales of securities of $6 million at December 31, 2014 and 2013.
-3	The fair value of securities in an unrealized loss position was $170 million and $299 million at December 31, 2014 and 2013, respectively.
The fair value of Virginia Power's marketable debt securities at December 31, 2014, by contractual maturity is as follows:
	Amount
(millions)
Due in one year or less	$	40
Due after one year through five years	180
Due after five years through ten years	242
Due after ten years	219
Total	$	681
Presented below is selected information regarding Virginia Power's marketable equity and debt securities.
Year Ended December 31,	2014			2013			2012
(millions)
Proceeds from sales	$	549		$	572		$	626
Realized gains(1)	73			52			42
Realized losses(1)	12			14			11
-1	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Virginia Power recorded other-than-temporary impairment losses on investments as follows:
Year Ended December 31,	2014			2013			2012
(millions)
Total other-than-temporary impairment losses(1)	$	8		$	15		$	11
Losses recorded to decommissioning trust regulatory liability	(4		)	(13		)	(10		)
Losses recorded in other comprehensive income (before taxes)	(2		)	(1		)	—
Net impairment losses recognized in earnings	$	2		$	1		$	1
-1	Amounts include other-than-temporary impairment losses for debt securities of $2 million, $9 million and $2 million at December 31, 2014, 2013 and 2012, respectively.
Equity Method Investments
Dominion and Dominion Gas
Investments that Dominion and Dominion Gas account for under the equity method of accounting are as follows:
Company	Ownership%		Investment Balance						Description
As of December 31,			2014			2013
(millions)
Dominion
Blue Racer Midstream, LLC	50	%	$	671		$	510		Midstream gas and related services
Fowler I Holdings LLC	50	%	134			149			Wind-powered merchant generation facility
NedPower Mount Storm LLC	50	%	128			131			Wind-powered merchant generation facility
Iroquois Gas Transmission System, LP	24.72	%	107			105			Gas transmission system
Other(1)	various		41			21
Total			$	1,081		$	916
Dominion Gas
Iroquois Gas Transmission System, LP	24.72	%	$	107		$	105		Gas transmission system
Total			$	107		$	105
(1) Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018. Includes Dominion's investment in Atlantic Coast Pipeline. See Note 15 for more information.
Dominion's equity earnings on its investments totaled $46 million, $14 million and $25 million in 2014, 2013 and 2012, respectively. Dominion received distributions from these investments of $60 million, $33 million and $58 million in 2014, 2013, and 2012, respectively. As of December 31, 2014 and 2013, the carrying amount of Dominion's investments exceeded its share of underlying equity in net assets by approximately $126 million and $36 million, respectively. $87 million of the differences relate to basis differences from Dominion's investments in Blue Racer and wind projects, which are being amortized over the useful lives of the underlying assets. The remaining $39 million of differences reflect equity method goodwill and are not being amortized.
Dominion Gas' equity earnings on its investment totaled $21 million, $22 million and $23 million in 2014, 2013 and 2012, respectively. Dominion Gas received distributions from its investment of $20 million, $19 million and $25 million in 2014, 2013, and 2012, respectively. As of December 31, 2014 and 2013, the carrying amount of Dominion Gas' investment exceeded its share of underlying equity in net assets by approximately $8 million. The differences reflect equity method goodwill and are not being amortized.
Equity earnings are recorded in other income in Dominion's and Dominion Gas' Consolidated Statements of Income.
Blue Racer
In December 2012, Dominion formed a joint venture 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 December 2012, East Ohio sold two pipeline systems to an affiliate who then contributed those systems to Blue Racer. East Ohio received consideration of $248 million, consisting of $61 million in cash proceeds and the extinguishment of affiliated long term debt of $187 million. The transaction resulted in a gain of approximately $176 million ($110 million after-tax) that is recognized in other operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. Dominion recorded a 50% interest in Blue Racer and cash proceeds of $115 million for the contribution of the assets to the joint venture. Dominion recognized a gain of $72 million ($43 million after-tax), net of transaction fees of $9 million, which is recorded in other operations and maintenance expense in Dominion's Consolidated Statements of Income.
In March 2013, DTI sold Line TL-404 to an affiliate, that subsequently sold line TL-404 to Blue Racer for cash proceeds of approximately $47 million. The sale resulted in a gain of approximately $25 million ($14 million after-tax) net of a $2 million write-off of goodwill, and is included in other operations and maintenance expense in both Dominion Gas' and Dominion's Consolidated Statement of Income.
Phase 1 of Natrium was completed in the second quarter of 2013 and was contributed by Dominion 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, DTI sold Line TPL-2A to an affiliate, that subsequently sold Line TPL-2A to Blue Racer, and sold Line TL-388 to Blue Racer and received approximately $78 million in cash proceeds. The sales resulted in an approximately $74 million ($41 million after-tax) gain which is included in other operations and maintenance expense in both Dominion Gas' and Dominion’s Consolidated Statements of Income.
In the fourth quarter of 2013, DTI sold the Western System to an affiliate, that subsequently sold the Western System to Blue Racer for cash proceeds of approximately $30 million. The sale resulted in a gain of approximately $3 million ($2 million after-tax) for DTI and $4 million ($2 million after-tax) for Dominion and is included in other operations and maintenance expense in both Dominion Gas' and Dominion's Consolidated Statement of Income.
Dominion NGL Pipelines, LLC was contributed in January 2014 by Dominion to Blue Racer, prior to commencement of service, resulting in an increased equity method investment of $155 million, including $6 million of goodwill allocated from Dominion's goodwill balance to its equity method investment in Blue Racer.
In March 2014, Dominion Gas sold the Northern System to an affiliate, that subsequently sold the Northern System to Blue Racer for consideration of approximately $84 million. Dominion Gas' consideration consisted of $17 million in cash proceeds and the extinguishment of affiliated current borrowings of $67 million and Dominion's consideration consisted of cash proceeds of approximately $84 million. The sale resulted in a gain of approximately $59 million ($35 million after-tax for Dominion Gas and $34 million after-tax for Dominion) net of a $3 million write-off of goodwill, and is included in other operations and maintenance expense in both Dominion Gas' and Dominion's Consolidated Statements of Income.
Dominion
Atlantic Coast Pipeline
In September 2014, Dominion, along with Duke Energy Corporation, Piedmont Natural Gas Company, Inc. and AGL Resources Inc., announced the formation of Atlantic Coast Pipeline. The members, which are subsidiaries of the above-referenced parent companies, hold the following membership interests: Dominion, 45%; Duke Energy Corporation, 40%; Piedmont Natural Gas Company, Inc., 10%; and AGL Resources Inc., 5%. Atlantic Coast Pipeline is focused on constructing an approximately 550-mile natural gas pipeline running from West Virginia through Virginia to North Carolina. Subsidiaries and affiliates of all four members plan to be customers of the pipeline under 20-year contracts, pending regulatory approvals. PSNC Energy also plans to be a customer of the pipeline under a 20-year contract, pending regulatory approvals. Atlantic Coast Pipeline is considered an equity method investment as Dominion has the ability to exercise significant influence, but not control, over the investee. See Note 15 for more information.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment, Net [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT
	Major classes of property, plant and equipment and their respective balances for the Companies are as follows:
	At December 31,	2014			2013
	(millions)
	Dominion
	Utility:
	Generation	$	15,193		$	14,018
	Transmission	9,897			8,686
	Distribution	12,354			11,714
	Storage	2,350			2,190
	Nuclear fuel	1,411			1,375
	Gas gathering and processing	791			787
	General and other	845			812
	Other-including plant under construction	3,633			3,261
	Total utility	46,474			42,843
	Nonutility:
	Merchant generation-nuclear	1,267			1,153
	Merchant generation-other	2,023			1,328
	Nuclear fuel	860			770
	Other-including plant under construction	782			875
	Total nonutility	4,932			4,126
	Total property, plant and equipment	$	51,406		$	46,969
	Virginia Power
	Utility:
	Generation	$	15,193		$	14,018
	Transmission	5,884			4,959
	Distribution	9,526			9,103
	Nuclear fuel	1,411			1,375
	General and other	697			668
	Other-including plant under construction	2,464			2,719
	Total utility	35,175			32,842
	Nonutility-other	5			6
	Total property, plant and equipment	$	35,180		$	32,848
	Dominion Gas
	Utility:
	Transmission	$	3,690		$	3,407
	Distribution	2,530			2,333
	Storage	1,466			1,314
	Gas gathering and processing	786			783
	General and other	111			103
	Plant under construction	179			175
	Total utility	8,762			8,115
	Nonutility:
	E&P properties being amortized and other	140			125
	Total nonutility	140			125
	Total property, plant and equipment	$	8,902		$	8,240
	There were no significant E&P properties under development, as defined by the SEC, excluded from Dominion Gas' amortization at December 31, 2014. As gas and oil reserves are proved through drilling or as properties are deemed to be impaired, excluded costs and any related reserves are transferred on an ongoing, well-by-well basis into the amortization calculation.
	Jointly-Owned Power Stations
	Dominion's and Virginia Power's proportionate share of jointly-owned power stations at December 31, 2014 is as follows:
		Bath			North			Clover			Millstone
		County			Anna Units 1 and 2(1)			Power			Unit 3(2)
		Pumped						Station(1)
		Storage
		Station(1)
	(millions, except percentages)
	Ownership interest	60		%	88.4		%	50		%	93.5		%
	Plant in service	$	1,039		$	2,426		$	573		$	1,104
	Accumulated depreciation	(542		)	(1,137		)	(206		)	(290		)
	Nuclear fuel	—			627			—			480
	Accumulated amortization of nuclear fuel	—			(486		)	—			(342		)
	Plant under construction	11			114			11			71
	-1	Units jointly owned by Virginia Power.
	-2	Unit jointly owned by Dominion.
	The co-owners are obligated to pay their share of all future construction expenditures and operating costs of the jointly-owned facilities in the same proportion as their respective ownership interest. Dominion and Virginia Power report their share of operating costs in the appropriate operating expense (electric fuel and other energy-related purchases, other operations and maintenance, depreciation, depletion and amortization and other taxes, etc.) in the Consolidated Statements of Income.
Assignments of Marcellus Acreage
In December 2013, DTI closed on agreements with two natural gas producers to convey over time approximately 100,000 acres of Marcellus Shale development rights underneath several of its natural gas storage fields.  The agreements provide for payments to DTI, subject to customary adjustments, of approximately $200 million over a period of nine years, and an overriding royalty interest in gas produced from the acreage. In 2013, DTI received approximately $100 million in cash proceeds, resulting in an approximately $20 million ($12 million after-tax) gain, recorded to operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. During the twelve months ended December 31, 2014, DTI received $16 million in additional cash proceeds resulting from post-closing adjustments. At December 31, 2014, deferred revenue totaled approximately $85 million, which is expected to be recognized over the remaining term of the agreement.
In November 2014, DTI closed an agreement with a natural gas producer to convey over time approximately 24,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields. The agreement provides for payments to DTI, subject to customary adjustments, of approximately $120 million over a period of four years, and an overriding royalty interest in gas produced from the acreage. In November 2014, DTI closed on the agreement and received proceeds of approximately $60 million associated with an initial conveyance of approximately 12,000 acres, resulting in an approximately $60 million ($36 million after-tax) gain, recorded to operations and maintenance expense in Dominion Gas' Consolidated Statements of Income.
In November 2014, DTI signed an agreement with a natural gas producer to convey approximately 11,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields. The agreement provides for a payment to DTI, subject to customary adjustments, of approximately $27 million, and an overriding royalty interest in gas produced from the acreage. DTI expects to close on the agreement in March 2015.

Goodwill_and_Intangible_Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	GOODWILL AND INTANGIBLE ASSETS
	Goodwill
	The changes in Dominion's and Dominion Gas' carrying amount and segment allocation of goodwill are presented below:
		Dominion				Dominion				DVP			Corporate and		Total
		Generation				Energy							Other(1)
	(millions)
	Dominion
	Balance at December 31, 2012(2)	$	1,503			$	701			$	926		$	—	$	3,130
	Asset disposition adjustment	(19		)	(3)	(25		)	(4)	—			—		(44		)
	Balance at December 31, 2013(2)	$	1,484			$	676			$	926		$	—	$	3,086
	Asset disposition adjustment	(32		)	(3)	(10		)	(4)	—			—		(42		)
	Balance at December 31, 2014(2)	$	1,452			$	666			$	926		$	—	$	3,044
	Dominion Gas
	Balance at December 31, 2012(2)	$	—			$	552			$	—		$	—	$	552
	Asset disposition adjustment	—				(7		)	(4)	—			—		(7		)
	Balance at December 31, 2013(2)	$	—			$	545			$	—		$	—	$	545
	Asset disposition adjustment	—				(3		)	(4)	—			—		(3		)
	Balance at December 31, 2014(2)	$	—			$	542			$	—		$	—	$	542
	-1	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.
	-2	Goodwill amounts do not contain any accumulated impairment losses.
	-3	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
	-4	Related to assets sold or contributed to an affiliate or Blue Racer.
	Other Intangible Assets
	The Companies' other intangible assets are subject to amortization over their estimated useful lives. Dominion's amortization expense for intangible assets was $71 million, $72 million and $82 million for 2014, 2013 and 2012, respectively. In 2014, Dominion acquired $115 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of approximately 15 years. Amortization expense for Virginia Power's intangible assets was $24 million for 2014 and $22 million each year for 2013 and 2012. In 2014, Virginia Power acquired $45 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of 14 years. Dominion Gas' amortization expense for intangible assets was $17 million, $16 million and $15 million for 2014, 2013 and 2012, respectively. In 2014, Dominion Gas acquired $8 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of approximately 7 years. The components of intangible assets are as follows:
	At December 31,	2014						2013
		Gross			Accumulated			Gross			Accumulated
		Carrying			Amortization			Carrying			Amortization
		Amount						Amount
	(millions)
	Dominion
	Software, licenses and other	$	877		$	312		$	867		$	308
	Emissions allowances	10			5			3			2
	Total	$	887		$	317		$	870		$	310
	Virginia Power
	Software, licenses and other	$	286		$	81		$	271		$	78
	Total	$	286		$	81		$	271		$	78
	Dominion Gas
	Software, licenses and other	$	192		$	113		$	180		$	98
	Total	$	192		$	113		$	180		$	98
	Annual amortization expense for these intangible assets is estimated to be as follows:
		2015			2016			2017			2018		2019
	(millions)
	Dominion	$	72		$	67		$	58		$	45	$	36
	Virginia Power	$	21		$	18		$	15		$	12	$	8
	Dominion Gas	$	17		$	16		$	13		$	11	$	11

Regulatory_Assets_and_Liabilit

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets and Liabilities	REGULATORY ASSETS AND LIABILITIES
	Regulatory assets and liabilities include the following:
	At December 31,	2014		2013
	(millions)
	Dominion
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	124	$	89
	Deferred cost of fuel used in electric generation(2)	79		—
	Deferred nuclear refueling outage costs(3)	44		—
	Unrecovered gas costs(4)	36		50
	Other	64		78
	Regulatory assets-current	347		217
	Unrecognized pension and other postretirement benefit costs(5)	1,050		706
	Deferred rate adjustment clause costs(1)	250		287
	Income taxes recoverable through future rates(6)	133		155
	Derivatives(7)	101		16
	Other	108		64
	Regulatory assets-non-current	1,642		1,228
	Total regulatory assets	$	1,989	$	1,445
	Regulatory liabilities:
	PIPP(8)	$	71	$	76
	Other	99		52
	Regulatory liabilities-current(9)	170		128
	Provision for future cost of removal and AROs(10)	1,072		1,028
	Nuclear decommissioning trust(11)	815		693
	Deferred cost of fuel used in electric generation(2)	6		90
	Other	98		190
	Regulatory liabilities-non-current	1,991		2,001
	Total regulatory liabilities	$	2,161	$	2,129
	Virginia Power
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	117	$	62
	Deferred cost of fuel used in electric generation(2)	79		—
	Deferred nuclear refueling outage costs(3)	44		—
	Other	58		66
	Regulatory assets-current	298		128
	Deferred rate adjustment clause costs(1)	179		227
	Derivatives(7)	101		16
	Income taxes recoverable through future rates(6)	100		124
	Other	59		50
	Regulatory assets-non-current	439		417
	Total regulatory assets	$	737	$	545
	Regulatory liabilities:
	Other	$	90	$	41
	Regulatory liabilities-current	90		41
	Provision for future cost of removal(10)	852		807
	Nuclear decommissioning trust(11)	815		693
	Deferred cost of fuel used in electric generation(2)	6		90
	Other	10		7
	Regulatory liabilities-non-current	1,683		1,597
	Total regulatory liabilities	$	1,773	$	1,638
	Dominion Gas
	Regulatory assets:
	Unrecovered gas costs(4)	$	29	$	40
	Deferred rate adjustment clause costs(1)	7		27
	UEX Rider(12)	—		11
	Other	2		1
	Regulatory assets-current	38		79
	Unrecognized pension and other postretirement benefit costs(5)	242		194
	Deferred rate adjustment clause costs(1)	71		59
	Income taxes recoverable through future rates(6)	24		24
	Other	42		8
	Regulatory assets-non-current	379		285
	Total regulatory assets	$	417	$	364
Regulatory liabilities:
PIPP(8)	$	71	$	76
Other	4		3
Regulatory liabilities-current	75		79
Provision for future cost of removal and AROs(10)	172		177
Unrecognized pension and other postretirement benefit costs(5)	—		18
Other	20		8
Regulatory liabilities-non-current	192		203
Total regulatory liabilities	$	267	$	282
-1	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects for Virginia Power. Reflects deferrals of costs associated with certain current and prospective rider projects for Dominion Gas. See Note 13 for more information.
-2	Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion's and Virginia Power’s generation operations. See Note 13 for more information. For 2014 and 2013, amount includes approximately $5 million related to DOE claims.
-3	Legislation enacted in Virginia in April 2014 requires Virginia Power to defer operation and maintenance costs incurred in connection with the refueling of any nuclear-powered generating plant. These deferred costs will be amortized over the refueling cycle, not to exceed 18 months.
-4	Reflects unrecovered gas costs at regulated gas operations, which are recovered through filings with the applicable regulatory authority.
-5	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.
-6	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.
-7	As discussed under Derivative Instruments in Note 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.
-8	Under PIPP, eligible customers can make reduced payments 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. See Note 13 for more information.
-9	Current regulatory liabilities are presented in other current liabilities in Dominion'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	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.
-12	Represents East Ohio’s deferrals for the UEX Rider which are recovered through rates which are filed annually. Most of East Ohio’s bad debt expense is recovered either through the UEX Rider or the PIPP Rider. See Note 13 for more information.
At December 31, 2014, approximately $218 million of Dominion's, $165 million of Virginia Power's and $45 million of Dominion Gas' regulatory assets represented past expenditures on which they do not currently earn a return. The majority of these expenditures are expected to be recovered within the next two years.

Regulatory_Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2014
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, the Companies 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, involves elements of judgment and significant uncertainties and 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 the Companies' 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 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. 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.  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.
	In March 2014, FERC issued an order excluding from Virginia Power's transmission rates for wholesale transmission customers located outside Virginia the incremental costs of undergrounding certain transmission line projects. FERC found it is not just and reasonable for non-Virginia wholesale transmission customers to be allocated the incremental costs of undergrounding the facilities because the projects are a direct result of Virginia legislation and Virginia Commission pilot programs intended to benefit the citizens of Virginia. The order is retroactively effective as of March 2010 and will cause the reallocation of the costs charged to wholesale transmission customers with loads outside Virginia to wholesale transmission customers with loads in Virginia. FERC determined that there was not sufficient evidence on the record to determine the magnitude of the underground increment and ordered a hearing to determine the appropriate amount of undergrounding cost to be allocated to each wholesale transmission customer in Virginia. While Virginia Power cannot predict the outcome of the hearing, it is not expected to have a material effect on results of operations.
	Other Regulatory Matters
	Electric Regulation in Virginia
	The Regulation Act enacted in 2007 instituted a cost-of-service rate model, ending Virginia's planned transition to retail competition for electric supply service to most classes of customers.
	The Regulation Act authorizes stand-alone rate adjustment clauses for recovery of costs for new generation projects, FERC-approved transmission costs, environmental compliance, conservation and energy efficiency programs and renewable energy programs, and also contains statutory provisions directing Virginia Power to file annual fuel cost recovery cases with the Virginia Commission. As amended, it provides for enhanced returns on capital expenditures on specific newly-proposed generation projects.
	If the Virginia Commission's future rate decisions, including actions relating to Virginia Power's rate adjustment clause filings, differ materially from Virginia Power's expectations, it may adversely affect its results of operations, financial condition and cash flows.
	2013 Biennial Review
	Pursuant to the Regulation Act, in March 2013, Virginia Power submitted its base rate filings and accompanying schedules in support of the Virginia Commission's 2013 biennial review of Virgina Power's rates, terms and conditions, as well as of Virginia Power's earnings for 2011 and 2012 test periods. The Virginia Power earnings test analysis reviewed by the Virginia Commission reflected an ROE of 10.30% on its generation and distribution services earnings for the combined test periods.
	In November 2013, the Virginia Commission issued its 2013 Biennial Review Order. After deciding eleven contested earnings test adjustments, the Virginia Commission ruled that Virginia Power earned on average an ROE of approximately 10.25% on its generation and distribution services for the combined 2011 and 2012 test periods. Because this ROE was more than 50 basis points below Virginia Power’s authorized ROE of 10.9%, the Virginia Commission authorized the deferred recovery, for earnings test purposes, of $23 million in costs related to asset impairments with early retirement decisions, severe weather events, and natural disasters to be amortized over the 2013 calendar year. The Virginia Commission did not order a base rate increase because Virginia Power had previously waived its right to any such increase, and because it determined that Virginia Power had a revenue sufficiency of approximately $280 million when projecting the annual revenues generated by base rates to the revenues required to cover costs of service and earn a fair return. As part of its revenue sufficiency determination, the Virginia Commission also made findings on eleven rate case adjustments, in addition to changes to the cost of capital and capital structure, which resulted in changes to Virginia Power’s rate year revenues and expenses, and Virginia Power’s rate base for generation and distribution, for the rate year beginning January 1, 2014. Virginia Power incurred a $55 million ($37 million after-tax) charge in connection with the 2013 Biennial Review Order.
	In its 2013 Biennial Review Order, the Virginia Commission also set the ROE that will be used in Virginia Power’s 2015 biennial review earnings test analysis for earnings on generation and distribution services for the combined 2013 and 2014 test periods, and that will be applied to Riders R, S, W, B, BW, C1A, and C2A. Pursuant to the Regulation Act, Virginia Power’s authorized ROE can be no lower than the average of the returns reported for the three previous years by not less than a majority of comparable utilities in the Southeastern U.S., subject to certain limitations as described in the Regulation Act. Following this statutory peer group analysis, the Virginia Commission determined that the peer group floor ROE for Virginia Power was 9.89%. It further held, declining to increase or decrease Virginia Power’s combined rate of return based on performance, that Virginia Power’s ROE for earnings test purposes in its 2015 biennial review and for rate adjustment clause purposes is 10.0%, consistent with its determination that Virginia Power’s market cost of equity is 10.0%.
	Virginia Fuel Expenses
	In May 2014, Virginia Power submitted its annual fuel factor filing to the Virginia Commission to recover an estimated $1.9 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, 2014. Virginia Power also offered to defer recovery of 50% of its total estimated $268 million jurisdictional deferred fuel balance to the 2015-2016 fuel year, thereby recovering $134 million of its jurisdictional deferred fuel balance for the rate year beginning July 1, 2014. In September 2014, the Virginia Commission approved Virginia Power’s increased fuel rate, which was already in effect on an interim basis since July 1, 2014. The new rate includes approval of Virginia Power's offer to defer recovery of 50% its jurisdictional deferred fuel balance and represents an annual fuel revenue increase of approximately $300 million.
	Rate Adjustment Clauses
	Below is a discussion of significant riders associated with various Virginia Power projects:
	•	The Virginia Commission previously approved Rider T1. In July 2014, the Virginia Commission approved an approximately $538 million revenue requirement for the rate year beginning September 1, 2014, which represents an approximately $134 million increase over the previous year.
	•	The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2014, Virginia Power proposed an approximately $244 million revenue requirement for the rate year beginning April 1, 2015. This case is pending.
	•	The Virginia Commission previously approved Rider W in conjunction with Warren County. In February 2015, the Virginia Commission approved an approximately $135 million revenue requirement for the rate year beginning April 1, 2015.
	•	The Virginia Commission previously approved Rider BW in connection with Brunswick County. In October 2014, Virginia Power proposed a total revenue requirement of approximately $111 million for the rate year beginning September 1, 2015. This case is pending.
	•	The Virginia Commission previously approved Riders C1A and C2A in connection with cost recovery for DSM programs. In August 2014, Virginia Power proposed a total revenue requirement of approximately $47 million for the rate year beginning May 1, 2015. Virginia Power further proposed three new energy efficiency programs for Virginia Commission approval with a requested five-year cost cap of approximately $106 million for those programs. This case is pending.
	•	The Virginia Commission previously approved Rider R in conjunction with Bear Garden. In June 2014, Virginia Power proposed an approximately $84 million revenue requirement for the rate year beginning April 1, 2015. This case is pending.
	•	Virginia legislation which provides for the recovery of costs to move certain electric distribution lines underground became effective in July 2014. In October 2014, Virginia Power filed for approval of Rider U, which proposes a revenue requirement of approximately $28 million during the initial rate year beginning September 1, 2015. This case is pending.
	•	The Virginia Commission previously approved Rider B in conjunction with the conversion of three power stations to biomass. In June 2014, Virginia Power proposed an approximately $13 million revenue requirement for the rate year beginning April 1, 2015. This case is pending.
	•	In January 2015, Virginia Power applied for a CPCN to construct and operate a new 20 MW utility-scale solar facility near its existing Remington Power Station in Fauquier County, Virginia. Virginia Power also applied for approval of Rider US-1 to recover the costs of the facility. The total cost of the Remington Solar Facility is approximately $47 million (excluding financing costs). This case is pending.
	Brunswick County
	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 November 2013, the Virginia Commission denied reconsideration.  Three appeals were filed with the Supreme Court of Virginia, but two were withdrawn.  In September 2014, the Supreme Court of Virginia issued an opinion affirming the Virginia Commission’s decision in the remaining appeal.
	Electric Transmission Project
	In November 2013, the Virginia Commission issued an order granting Virginia Power a CPCN to construct approximately 7 miles of new overhead 500 kV transmission line from the existing Surry Switching Station in Surry County to a new Skiffes Creek Switching Station in James City County, and approximately 20 miles of new 230 kV transmission line in James City County, York County, and the City of Newport News from the proposed new Skiffes Creek Switching Station to Virginia Power’s existing Whealton Substation in the City of Hampton. In February 2014, the Virginia Commission granted reconsideration requested by Virginia Power and issued an Order Amending Certificate. Several appeals were filed with the Supreme Court of Virginia and oral arguments were heard in January 2015. The appeals are pending.
	North Anna
	Virginia Power is considering the construction of a third nuclear unit at a site located at North Anna. If Virginia Power decides to build a new unit, it must first receive a COL from the NRC, approval of the Virginia Commission and certain environmental permits and other approvals. In April 2013, Virginia Power decided to replace the reactor design previously selected for a potential unit with ESBWR technology. 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 filed the second part of the amendment in December 2013. The COL is expected in 2016. Virginia Power has not yet committed to building a new nuclear unit at North Anna.
	In June 2012, the U.S. Court of Appeals for the D.C. Circuit vacated and remanded a 2010 NRC decision and related rulemaking that generically assessed the environmental impacts of spent fuel storage after expiration of a reactor’s license until a repository became available. In August 2012, the NRC partially granted a petition filed by BREDL and other petitioners in a number of ongoing licensing proceedings, including the North Anna COL proceedings, to withhold issuance of licenses until completion of action on the remand, and held proposed contentions accompanying the petition in abeyance. In August 2014, the NRC approved a new final rule codifying the NRC’s further generic assessment of environmental impacts of continued storage of spent fuel and lifted the suspension of final licensing decisions in pending cases and dismissed pending contentions on the subject, including the proposed contention filed by BREDL.
	In September 2014, BREDL filed a new petition with the NRC again seeking suspension of final decision making in the COL proceeding, along with motions to reopen and file a new contention. The new filings assert that the NRC must make a safety finding on the feasibility and capacity of geologic disposal of spent fuel as a prerequisite to issuance of a license. The filings alleged that because these safety findings are no longer made as part of the NRC’s new continued storage rule, such findings must now be made in individual licensing proceedings. In January 2015, BREDL filed another petition in the COL proceeding asking the NRC to order supplementation of the final environmental impact statement for North Anna 3 to incorporate the NRC's generic assessment of the impacts of continued spent fuel storage, so that BREDL could then challenge that assessment. BREDL's September 2014 filings and January 2015 petition are substantially the same as filings made by various other intervenor groups in other licensing proceedings pending before the NRC. Resolution of these filings is not expected to affect the schedule for issuance of the COL.
	North Anna and Offshore Wind Legislation
	In April 2014, legislation was enacted in Virginia that permits Virginia Power to recover 70% of the costs previously deferred or capitalized related to the development of a third nuclear unit located at North Anna and offshore wind facilities through December 31, 2013 as part of the 2013 and 2014 base rates. Virginia Power had deferred or capitalized costs totaling approximately $577 million for these projects as of December 31, 2013, substantially all of which relate to North Anna. For the 70% portion of these previously deferred or capitalized costs allocable to customers in Virginia, Virginia Power recognized such amounts that are now recoverable in 2013 and 2014 base rates as charges against net income beginning in the second quarter of 2014 and for the remainder of the year. During 2014, Virginia Power recognized $374 million ($248 million after-tax) in charges against income representing the cumulative recovery of costs from January 2013 through December 2014, which are primarily included in other operations and maintenance expense in the Consolidated Statements of Income. The remaining deferred or capitalized costs, as well as costs incurred after December 31, 2013, continue to be eligible for inclusion in a future rate adjustment clause.
	Regulation Act Legislation
	In February 2015, the Virginia Governor signed legislation into law which will keep Virginia Power’s base rates unchanged until at least December 1, 2022. In addition, no biennial reviews will be conducted by the Virginia Commission for the five successive 12-month test periods beginning January 1, 2015, and ending December 31, 2019. Virginia Power is scheduled to file its next biennial review, covering 2013 and 2014, in March 2015. The legislation allows this review to proceed for the sole purpose of determining whether any refunds are due to customers based on earnings performance during the 2013 and 2014 test periods. In addition the legislation requires the Virginia Commission to conduct proceedings in 2017 and 2019 to determine the utility's ROE for use in connection with the rate adjustment clauses and require utilities to file integrated resource plans annually rather than biennially. The legislation requires Virginia Power to write-off $85 million of prior-period deferred fuel costs during the first quarter of 2015. In addition, the legislation requires the Virginia Commission to implement a fuel rate reduction for Virginia Power as soon as practicable based on this non-recovery as well as any over-recovery for the 2014-2015 fuel year and projected fuel expense for the 2015-2016 fuel year. The legislation also deems the construction or purchase of one or more utility-scale solar facilities located in Virginia up to 500 MW in total is deemed to be in the public interest.
	North Carolina Regulation
	In December 2012, the North Carolina Commission approved a $36 million increase in Virginia Power’s annual non-fuel base revenues based on an authorized ROE of 10.2%, and a $14 million decrease in annual base fuel revenues for a combined total base revenue increase of $22 million. These rate changes became effective on January 1, 2013 and were appealed to the North Carolina Supreme Court by multiple parties. In June 2014, the Supreme Court of North Carolina issued an opinion reversing the portion of the North Carolina Commission’s December 2012 order from Virginia Power’s 2012 base rate case approving a 10.2% ROE for Virginia Power, and remanding the case to the North Carolina Commission for additional findings of fact in light of a 2013 opinion issued after the North Carolina Commission’s order. This case is pending.
	In December 2014, the North Carolina Commission issued an order approving an approximately $17 million increase to the fuel component of Virginia Power’s electric rates for the rate year beginning January 1, 2015. This increase includes the approval of Virginia Power’s mitigation proposal to defer recovering 50% of its estimated $17 million jurisdictional deferred fuel balance to the 2016 fuel year, without interest.
	Ohio Regulation
	PIR Program
	In 2008, East Ohio began PIR, aimed at replacing approximately 25% of its pipeline system. In February 2014, East Ohio filed an application requesting approval to adjust the PIR cost recovery rates for 2013 costs. The filing reflects gross plant investment for 2013 of $164 million, cumulative gross plant investment of $674 million and an estimated revenue requirement of $89 million. This application was approved by the Ohio Commission in April 2014.
	In February 2015, East Ohio filed an application to adjust the PIR cost recovery for 2014 costs. The filing reflects gross plant investment for 2014 of $155 million, cumulative gross plant investment of $829 million and a revenue requirement of$108 million. This case is pending.
	AMR Program
	In 2007, East Ohio began installing automated meter reading technology for its 1.2 million customers in Ohio. In May 2014, AMR cost recovery rates became effective as approved by the Ohio Commission in April 2014. The approval includes a revenue requirement of $8 million, which represents an approximately $3 million increase over the previous year.
	In January 2013, East Ohio filed with the Ohio Supreme Court an appeal of a rate reduction ordered by the Ohio Commission in October 2012 and a motion seeking a stay of the AMR cost recovery rate imposed. The Ohio Supreme Court granted the stay in March 2013 and East Ohio put the higher AMR cost recovery rate filed by East Ohio into effect. In July 2014, the Ohio Supreme Court ruled in East Ohio’s favor by agreeing that the rate reduction imposed by the Ohio Commission was unreasonable.
	In February 2015, East Ohio filed its application with the Ohio Commission to adjust its AMR cost recovery charge to recover costs for calendar year 2014 associated with AMR deployment, which was completed in 2012. The filing reflects a projected revenue requirement of approximately $8 million. This case is pending.
	The AMR program approved by the Ohio Commission is now complete. Although no further capital investment will be added, East Ohio is approved to recover depreciation, property taxes, carrying charges and a return until East Ohio has another rate case.
	PIPP Plus Program
	Under the Ohio PIPP Plus Program, eligible customers can make reduced payments based on their ability to pay their bill. The difference between the customer’s total bill and the PIPP payment plan amount is deferred and collected under the PIPP Rider in accordance with the rules of the Ohio Commission. In July 2014, East Ohio’s annual update of the PIPP Rider was automatically approved by the Ohio Commission after a 45-day waiting period from the date of the filing. The increased rider rate reflects the refund over the next year of an over-recovery of accumulated arrearages of approximately $82 million as of March 31, 2014, net of projected deferred program costs of approximately $96 million for the period from April 2014 through June 2015.
	UEX Rider
	East Ohio has approval for a UEX Rider through which it recovers the bad debt expense of most customers not participating in the PIPP Plus Program. The UEX Rider is adjusted annually to achieve dollar for dollar recovery of East Ohio’s actual write-offs of uncollectible amounts. In July 2014, the Ohio Commission approved a decrease to East Ohio’s UEX Rider, which reflects the elimination of the over-recovered balance of accumulated bad debt expense of approximately $8 million as of March 31, 2014, and recovery of prospective bad debt expense projected to total approximately $25 million for the twelve-month period from April 2014 to March 2015.
	House Bill 95
	Ohio enacted utility reform legislation under House Bill 95, which became effective in September 2011. This law updates natural gas legislation by enabling gas companies to include more up-to-date cost levels when filing rate cases. It also allows gas companies to seek approval of capital expenditure plans under which gas companies can recognize carrying costs on associated capital investments placed in service and can defer the carrying costs plus depreciation and property tax expenses for recovery from ratepayers in the future. In July 2014, the Ohio Commission approved East Ohio’s application requesting authority to implement a capital expenditure program for 2014 capital expenditures totaling $110 million.
	FERC Regulation
	DTI Fuel Settlement
	In mid-2013, DTI received concerns about its fuel retainage percentages and apparent over-recovery of fuel costs during certain time periods reflected in its annual fuel reports. In December 2013, DTI submitted for FERC approval a stipulation and agreement addressing, among other things, reductions in its fuel retainage percentages and a rate moratorium through 2016. In February 2014, FERC approved the stipulation and agreement.  The revised fuel retainage percentages became effective January 1, 2014. DTI began assessing the reduced fuel retainage percentages on March 1, 2014, and as a result provided refunds totaling nearly $10 million. The refunds reflect, with interest, the value of the difference between the actual quantities of fuel retained for the months of January and February and the quantities that would have been retained using the reduced percentages.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation [Abstract]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS
	AROs represent obligations that result from laws, statutes, contracts and regulations related to the eventual retirement of certain of the Companies' long-lived assets. Dominion's and Virginia Power's AROs are primarily associated with the decommissioning of their nuclear generation facilities and also include those for the future abatement of asbestos expected to be disturbed in their generation facilities. Dominion Gas' AROs primarily include plugging and abandonment of gas and oil wells and the interim retirement of natural gas gathering, transmission, distribution and storage pipeline components.
	The Companies have also identified, but not recognized, AROs related to retirement of Dominion's LNG facility, Dominion Gas' gas storage wells in its underground natural gas storage network, certain Virginia Power electric transmission and distribution assets located on property with easements, rights of way, franchises and lease agreements, Virginia Power's hydroelectric generation facilities and the abatement of certain asbestos not expected to be disturbed in Dominion's and Virginia Power's generation facilities. The Companies currently do not have sufficient information to estimate a reasonable range of expected retirement dates for any of these assets since the economic lives of these assets can be extended indefinitely through regular repair and maintenance and they currently have no plans to retire any of these assets. As a result, a settlement date is not determinable for these assets and AROs for these assets will not be reflected in the Consolidated Financial Statements until sufficient information becomes available to determine a reasonable estimate of the fair value of the activities to be performed. The Companies continue to monitor operational and strategic developments to identify if sufficient information exists to reasonably estimate a retirement date for these assets. The changes to AROs during 2013 and 2014 were as follows:
		Amount
	(millions)
	Dominion
	AROs at December 31, 2012(1)	$	1,705
	Obligations incurred during the period	13
	Obligations settled during the period	(68		)
	Revisions in estimated cash flows(2)	(129		)
	Accretion	86
	Other	(29		)
	AROs at December 31, 2013(1)	$	1,578
	Obligations incurred during the period	40
	Obligations settled during the period	(82		)
	Revisions in estimated cash flows(3)	102
	Accretion	81
	Other	(5		)
	AROs at December 31, 2014(1)	$	1,714
	Virginia Power
	AROs at December 31, 2012	$	705
	Obligations incurred during the period	2
	Obligations settled during the period	(2		)
	Revisions in estimated cash flows(2)	(52		)
	Accretion	38
	Other	(2		)
	AROs at December 31, 2013	$	689
	Obligations incurred during the period	28
	Obligations settled during the period	(1		)
	Revisions in estimated cash flows(3)	108
	Accretion	37
	Other	(6		)
	AROs at December 31, 2014(4)	$	855
	Dominion Gas
	AROs at December 31, 2012	$	133
	Obligations incurred during the period	8
	Obligations settled during the period	(13		)
	Accretion	8
	Other	1
	AROs at December 31, 2013(5)(6)	$	137
	Obligations incurred during the period	2
	Obligations settled during the period	(8		)
	Accretion	8
	Other	8
	AROs at December 31, 2014(5)(6)	$	147
	-1	Includes $64 million, $94 million and $81 million reported in other current liabilities at December 31, 2012, 2013, and 2014, respectively.
	-2	Primarily reflects lower anticipated nuclear decommissioning costs.
	-3	Relates primarily to a shift of the delayed planned date on which the DOE is expected to begin accepting spent nuclear fuel.
	-4	Includes $7 million reported in other current liabilities at December 31, 2014.
	-5	Includes $2 million and $7 million reported in other current liabilities at December 31, 2013 and 2014, respectively.
	-6	Includes $135 million and $140 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2013 and 2014, respectively.
	Dominion and Virginia Power have established trusts dedicated to funding the future decommissioning of their nuclear plants. At December 31, 2014 and 2013, the aggregate fair value of Dominion's trusts, consisting primarily of equity and debt securities, totaled $4.2 billion and $3.9 billion, respectively. At December 31, 2014 and 2013, the aggregate fair value of Virginia Power's trusts, consisting primarily of debt and equity securities, totaled $1.9 billion and $1.8 billion, respectively.

Variable_Interest_Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2014
Variable Interest Entities [Abstract]
Variable Interest Entities	VARIABLE INTEREST ENTITIES
	The primary beneficiary of a VIE is required to consolidate the VIE and to disclose certain information about its significant variable interests in the VIE. The primary beneficiary of a VIE is the entity that has both 1) the power to direct the activities that most significantly impact the entity's economic performance and 2) the obligation to absorb losses or receive benefits from the entity that could potentially be significant to the VIE.
	Dominion
	Through August 2013, Dominion leased the Fairless generating facility in Pennsylvania from Juniper, the lessor, which began commercial operations in June 2004. 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 during 2013.
	Dominion has an initial 45% membership interest in Atlantic Coast Pipeline. See Note 9 for more details regarding the nature of this entity. Dominion concluded that Atlantic Coast Pipeline is a VIE because it has insufficient equity to finance its activities without additional subordinated financial support. Dominion has concluded that it is not the primary beneficiary of Atlantic Coast Pipeline as it does not have the power to direct the activities of Atlantic Coast Pipeline that most significantly impact its economic performance, as the power to direct is shared among multiple unrelated parties. Dominion is obligated to provide capital contributions based on its ownership percentage. Dominion's maximum exposure to loss is limited to its current and future investment.
	Dominion Gas
	DTI has been engaged to oversee the construction of, and to subsequently operate and maintain, the projects undertaken by Atlantic Coast Pipeline based on the overall direction and oversight of Atlantic Coast Pipeline's members. An affiliate of DTI holds a membership interest in Atlantic Coast Pipeline, therefore DTI is considered to have a variable interest in Atlantic Coast Pipeline. The members of Atlantic Coast Pipeline hold the power to direct the construction, operations and maintenance activities of the entity. DTI has concluded it is not the primary beneficiary of Atlantic Coast Pipeline as it does not have the power to direct the activities of Atlantic Coast Pipeline that most significantly impact its economic performance. DTI has no obligation to absorb any losses of the VIE. See Note 24 for information about associated related party receivable balances.
	Virginia Power
	Virginia Power has long-term power and capacity contracts with five 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 $639 million as of December 31, 2014. Virginia Power paid $223 million, $217 million, and $214 million for electric capacity and $138 million, $98 million, and $83 million for electric energy to these entities for the years ended December 31, 2014, 2013 and 2012, respectively.
	Virginia Power and Dominion Gas
	Virginia Power and Dominion Gas purchased shared services from DRS, an affiliated VIE, of approximately $335 million and $106 million, $331 million and $115 million, and $328 million and $107 million for the years ended December 31, 2014, 2013 and 2012, respectively. Virginia Power and Dominion Gas determined that each is not the most closely associated entity with DRS and therefore neither is the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Virginia Power and Dominion Gas. Virginia Power and Dominion Gas have no obligation to absorb more than their allocated shares of DRS costs.

ShortTerm_Debt_And_Credit_Agre

Short-Term Debt And Credit Agreements	12 Months Ended
	Dec. 31, 2014
Short-term Debt, Other Disclosures [Abstract]
Short-Term Debt And Credit Agreements	SHORT-TERM DEBT AND CREDIT AGREEMENTS
	The Companies 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.
	Dominion
	Commercial paper and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:
		Facility		Outstanding			Outstanding		Facility
		Limit		Commercial			Letters of		Capacity
				Paper			Credit		Available
	(millions)
	At December 31, 2014
	Joint revolving credit facility(1)	$	4,000	$	2,664		$	—	$	1,336
	Joint revolving credit facility(2)	500		111			48		341
	Total	$	4,500	$	2,775	(3)	$	48	$	1,677
	At December 31, 2013
	Joint revolving credit facility(1)	$	3,000	$	1,927		$	—	$	1,073
	Joint revolving credit facility(2)	500		—			11		489
	Total	$	3,500	$	1,927	(3)	$	11	$	1,562
	-1	In May 2014, this credit facility was amended and restated. The facility limit was increased from $3 billion to $4 billion and the maturity date was extended from September 2018 to April 2019. 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	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by Dominion's credit facilities were 0.38% and 0.33% at December 31, 2014 and 2013, respectively.
	Virginia Power
	Virginia Power's short-term financing is supported by two joint revolving credit facilities with Dominion and Dominion Gas. These credit facilities are being used for working capital, as support for the combined commercial paper programs of the Companies and for other general corporate purposes.
	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 and Dominion Gas were as follows:
		Facility Sub-limit		Outstanding Commercial Paper			Outstanding Letters of Credit		Facility Sub-limit Capacity Available
	(millions)
	At December 31, 2014
	Joint revolving credit facility(1)	$	1,250	$	1,250		$	—	$	—
	Joint revolving credit facility(2)	250		111			—		139
	Total	$	1,500	$	1,361	(3)	$	—	$	139
	At December 31, 2013
	Joint revolving credit facility(1)	$	1,000	$	842		$	—	$	158
	Joint revolving credit facility(2)	250		—			1		249
	Total	$	1,250	$	842	(3)	$	1	$	407
	-1	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. 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. In July 2014, Virginia Power increased its sub-limit from $1.0 billion to $1.25 billion. In January 2015, Virginia Power increased its sub-limit on this facility from $1.25 billion to $1.5 billion.
	-2	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. 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.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.36% and 0.33% at December 31, 2014 and 2013, respectively.
	In addition to the credit facility commitments mentioned above, Virginia Power also has a $120 million credit facility. In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. As of December 31, 2014, this facility supports approximately $119 million of certain variable rate tax-exempt financings of Virginia Power.
	Dominion Gas
	Dominion Gas's short-term financing is supported by the two joint revolving credit facilities discussed above with Dominion and Virginia Power, to which Dominion Gas was added as a borrower in May 2014. Dominion Gas’ current sub-limit under the $4 billion credit facility is $500 million, all of which was available at December 31, 2014, and can be increased or decreased multiple times per year, up to a maximum of $1 billion. Dominion Gas’ current sub-limit under the $500 million credit facility is $0 and can also be increased or decreased multiple times per year. The maturity date for both facilities is April 2019. In December 2014, Dominion Gas entered into a commercial paper program pursuant to which it began accessing the commercial paper markets in January 2015. Dominion Gas' current sub-limit under the $4 billion credit facility of $500 million is being used to support these commercial paper issuances.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2014
Long-term Debt, Unclassified [Abstract]
Long-Term Debt	LONG-TERM DEBT
	At December 31,	2014 Weighted-		2014			2013
		average
		Coupon(1)
	(millions, except percentages)
	Dominion Gas Holdings, LLC:
	Unsecured Senior Notes:
	1.05% and 2.5%, due 2016 and 2019	1.82	%	$	850		$	400
	3.55% to 4.8%, due 2023 to 2044	4.15	%	1,750			800
	Dominion Gas Holdings, LLC total principal			$	2,600		$	1,200
	Unamortized discount			(6		)	(2		)
	Dominion Gas Holdings, LLC total long-term debt			$	2,594		$	1,198
	Virginia Electric and Power Company:
	Unsecured Senior Notes:
	1.2% to 8.625%, due 2015 to 2019	5.06	%	$	2,471		$	2,488
	2.75% to 8.875%, due 2022 to 2044	5.07	%	5,592			4,643
	Tax-Exempt Financings(2):
	Variable rates, due 2016 to 2041	0.93	%	606			606
	0.70% to 5.6%, due 2022 to 2040	2.86	%	266			306
	Virginia Electric and Power Company total principal			$	8,935		$	8,043
	Securities due within one year	5.39	%	(211		)	(58		)
	Unamortized discount and premium, net			2			(11		)
	Virginia Electric and Power Company total long-term debt			$	8,726		$	7,974
	Dominion Resources, Inc.:
	Unsecured Senior Notes:
	Variable rates, due 2014 and 2015	0.36	%	$	400		$	400
	1.25% to 8.875%, due 2014 to 2019	3.17	%	3,150			4,391
	2.75% to 7.0%, due 2021 to 2044(3)	4.93	%	4,449			3,499
	Unsecured Convertible Senior Notes, 2.125%, due 2023			—			43
	Tax-Exempt Financing, variable rate, due 2041	1.1	%	75			75
	Unsecured Junior Subordinated Notes Payable to Affiliated Trust, 8.4%, due 2031	8.4	%	10			10
	Enhanced Junior Subordinated Notes:
	5.75% to 8.375%, due 2054 to 2066	6.28	%	985			985
	Variable rate, due 2066	2.54	%	380			380
	Remarketable Subordinated Notes, 1.07% to 1.50%, due 2019 to 2021	1.3	%	2,100			1,100
	Unsecured Debentures and Senior Notes(4):
	5.0% due 2014			—			600
	6.8% and 6.875%, due 2026 and 2027	6.81	%	89			89
	Dominion Energy, Inc.:
	Tax-Exempt Financing, 2.375%, due 2033	2.38	%	27			27
	Dominion Gas Holdings, LLC total principal (from above)			2,600			1,200
	Virginia Electric and Power Company total principal (from above)			8,935			8,043
	Dominion Resources, Inc. total principal			$	23,200		$	20,842
	Fair value hedge valuation(5)			19			55
	Securities due within one year(6)	3.3	%	(1,375		)	(1,519		)
	Unamortized discount and premium, net			(39		)	(48		)
	Dominion Resources, Inc. total long-term debt			$	21,805		$	19,330
	-1	Represents weighted-average coupon rates for debt outstanding as of December 31, 2014.
	-2	These financings relate to certain pollution control equipment at Virginia Power's generating facilities. Certain variable rate tax-exempt financings are supported by a $120 million credit facility that terminates in April 2019.
	-3	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015. As a result, at December 31, 2014, the notes were included in Securities due within one year in the Consolidated Balance Sheets.
	-4	Represents debt assumed by Dominion from the merger of its former CNG subsidiary.
	-5	Represents the valuation of certain fair value hedges associated with Dominion's fixed rate debt.
	-6	Includes $4 million fair value hedge valuation in 2014 and $14 million of fair value hedge valuation in 2013.
	Based on stated maturity dates rather than early redemption dates that could be elected by instrument holders, the scheduled principal payments of long-term debt at December 31, 2014, were as follows:
		2015			2016			2017			2018			2019			Thereafter			Total
	(millions, except percentages)
	Dominion Gas	$	—		$	400		$	—		$	—		$	450		$	1,750		$	2,600
	Weighted-average Coupon				1.05		%							2.5		%	4.15		%
	Virginia Power	$	211		$	476		$	679		$	850		$	350		$	6,369		$	8,935
	Weighted-average Coupon	5.39		%	5.24		%	5.43		%	4.17		%	5		%	4.64		%
	Dominion
	Unsecured Senior Notes(1)	$	861		$	1,308		$	1,354		$	1,350		$	2,000		$	11,878		$	18,751
	Tax-Exempt Financings	—			19			75			—			—			880			974
	Unsecured Junior Subordinated Notes Payable to Affiliated Trusts	—			—			—			—			—			10			10
Enhanced Junior Subordinated Notes	—			—			—			—			—			1,365			1,365
Remarketable Subordinated Notes	—			—			—			—			550			1,550			2,100
Total	$	861		$	1,327		$	1,429		$	1,350		$	2,550		$	15,683		$	23,200
Weighted-average Coupon	2.14		%	2.86		%	3.27		%	4.99		%	3.09		%	4.39		%
-1	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015. As a result, at December 31, 2014, the notes were included in Securities due within one year in the Consolidated Balance Sheets.
The Companies short-term credit facilities and long-term debt agreements contain customary covenants and default provisions. As of December 31, 2014, there were no events of default under these covenants.
Senior Note Redemptions
As part of Dominion's Liability Management Exercise, in December 2014, Dominion redeemed the following outstanding series of senior notes: 2005 Series C 5.15% Senior Notes due 2015, 2004 Series A 5.20% Senior Notes due 2016, 2006 Series A 5.60% Senior Notes due 2016, 2007 Series A 6.0% Senior Notes due 2017, and 2008 Series D 8.875% Senior Notes due 2019 with an aggregate outstanding principal of approximately $1.9 billion. The aggregate redemption price paid in December 2014 was approximately $2.2 billion and represents the principal amount outstanding, accrued and unpaid interest and the applicable make-whole premium of $263 million. Total charges for the Liability Management Exercise of $284 million, including the make-whole premium, were recognized and recorded in interest expense in Dominion's Consolidated Statements of Income. Proceeds from Dominion’s issuance of senior notes in November 2014 were used to offset the payment of the redemption price. Also see Convertible Securities called for redemption below.
Convertible Securities
As part of Dominion's Liability Management Exercise, in November 2014, Dominion provided notice to redeem all $22 million of outstanding contingent convertible senior notes. The senior notes were 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, when the notes were called for redemption by Dominion and upon the occurrence of certain other conditions. During 2014, the senior notes were eligible for conversion. During the first, second and third quarters of 2014, approximately $21 million of the notes were converted by holders into $23 million of common stock. In lieu of redemption, holders elected to convert the remaining $22 million of notes in December 2014 into $26 million of common stock. Proceeds from Dominion's issuance of senior notes in November 2014 were used to offset the portion of the conversions paid in cash. At December 31, 2014, all of the senior notes have been converted and none remain outstanding.
Junior Subordinated Notes Payable to Affiliated Trusts
In previous years, Dominion established several subsidiary capital trusts, each as a finance subsidiary of Dominion, which holds 100% of the voting interests. The trusts sold capital securities representing preferred beneficial interests and 97% beneficial ownership in the assets held by the trusts. In exchange for the funds realized from the sale of the capital securities and common securities that represent the remaining 3% beneficial ownership interest in the assets held by the capital trusts, Dominion issued various junior subordinated notes. The junior subordinated notes constitute 100% of each capital trust's assets. Each trust must redeem its capital securities when their respective junior subordinated notes are repaid at maturity or if redeemed prior to maturity.
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.
Interest charges related to Dominion's junior subordinated notes payable to affiliated trusts were $1 million for the years ended December 31, 2014 and 2013 and $21 million for the year ended December 31, 2012.
Enhanced Junior Subordinated Notes
In June 2006 and September 2006, Dominion issued $300 million of June 2006 hybrids and $500 million of September 2006 hybrids, respectively. The June 2006 hybrids bear interest at 7.5% per year until June 30, 2016. Thereafter, they will bear interest at the three-month LIBOR plus 2.825%, reset quarterly. The September 2006 hybrids bear interest at the three-month LIBOR plus 2.3%, reset quarterly.
In June 2009, Dominion issued $685 million of 8.375% June 2009 hybrids. The June 2009 hybrids were listed on the NYSE under the symbol DRU.
In October 2014, Dominion issued $685 million of October 2014 hybrids that will bear interest at 5.75% per year until October 1, 2024. Thereafter, they will bear interest at the three-month LIBOR plus 3.057%, reset quarterly.
Dominion may defer interest payments on the hybrids on one or more occasions for up to 10 consecutive years. If the interest payments on the hybrids are deferred, Dominion may not make distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments during the deferral period. 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 hybrids.
Dominion executed RCCs in connection with its issuance of the June 2006 hybrids, the September 2006 hybrids, and the June 2009 hybrids. Under the terms of the RCCs, Dominion covenants to and for the benefit of designated covered debtholders, as may be designated from time to time, that Dominion shall not redeem, repurchase, or defease all or any part of the hybrids, and shall not cause its majority owned subsidiaries to purchase all or any part of the hybrids, on or before their applicable RCC termination date, unless, subject to certain limitations, during the 180 days prior to such activity, Dominion has received a specified amount of proceeds as set forth in the RCCs from the sale of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than the applicable characteristics of the hybrids at that time, as more fully described in the RCCs. In September 2011, Dominion amended the RCCs of the June 2006 hybrids and September 2006 hybrids to expand the measurement period for consideration of proceeds from the sale of common stock issuances from 180 days to 365 days. In July 2014, Dominion amended the RCC of the June 2009 hybrids to expand the measurement period for consideration of proceeds from the sale of common stock or other equity-like issuances from 180 days to 365 days. The proceeds Dominion receives from the replacement offering, adjusted by a predetermined factor, must equal or exceed the redemption or repurchase price.
In 2012, Dominion launched a tender offer to purchase up to $150 million of September 2006 hybrids. Dominion purchased and canceled approximately $88 million of the September 2006 hybrids primarily as a result of this tender offer, which expired in 2012. As part of Dominion's Liability Management Exercise, in October 2014, Dominion redeemed all $685 million of the June 2009 hybrids plus accrued interest with the net proceeds from the issuance of the October 2014 hybrids. The redemption and all purchases were conducted in compliance with the RCCs.
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. In July 2014, Dominion issued $1 billion of 2014 Series A 6.375% Equity Units, initially in the form of Corporate Units. The Corporate Units are listed on the NYSE under the symbols DCUA, DCUB and DCUC, 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 per Corporate Unit 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 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.
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 and between 11.5 million and 14.3 million shares in July 2017. A total of 40.3 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(1)			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	$	553.5		$	550		1.18	%	4.82	%	$	79.3		7/1/16	7/1/19
7/1/14	20	$	982		$	1,000.00		1.5	%	4.875	%	$	142.8		7/1/17	7/1/20
-1	Payments of $66 million and $17 million were made in 2014 and 2013, respectively. The stock purchase contract liability was $216 million and $139 million at December 31, 2014 and 2013, respectively.
Dominion Gas Financing
In June 2014, Dominion Gas commenced an offer to exchange $1.2 billion principal amount of unsecured senior notes that were issued in a private placement in October 2013. The exchange offer satisfied Dominion Gas’ obligations under a registration rights agreement entered into in connection with the issuance of the Dominion Gas 2013 Senior Notes. The exchange offer did not represent a new financing transaction and there were no proceeds to Dominion Gas when the offer settled in August 2014.

Preferred_Stock

Preferred Stock	12 Months Ended
	Dec. 31, 2014
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Preferred Stock	PREFERRED STOCK
	Dominion is authorized to issue up to 20 million shares of preferred stock; however, none were issued and outstanding at December 31, 2014 or 2013.
	Virginia Power is authorized to issue up to 10 million shares of preferred stock, $100 liquidation preference, and had 2.59 million preferred shares issued and outstanding at December 31, 2013.
	During 2014, Virginia Power redeemed all outstanding series of its preferred stock. Upon redemption, each series was no longer outstanding for any purpose and dividends ceased to accumulate. Presented below is a summary of the preferred stock redemptions:
	Dividend	Total Shares	Redemption Price Per Share
		(thousands)
	$5.00	107	$	112.5	(1)
	4.04	13	102.27		(1)
	4.2	15	102.5		(1)
	4.12	32	103.73		(1)
	4.8	73	101		(1)
	7.05	500	100		(1)
	6.98	600	100		(1)
	Flex Money Market Preferred 12/02, Series A	1,250	100		(2)
	Total	2,590
	-1	As part of Dominion's Liability Management Exercise, in September 2014, Virginia Power provided irrevocable notice to redeem all shares outstanding for each series of preferred stock. In October 2014, the stock was redeemed at the applicable price per share plus accumulated and unpaid dividends.
	-2	In February 2014, Virginia Power provided irrevocable notice to redeem the stock. In March 2014, the stock was redeemed at the applicable price per share plus accumulated and unpaid dividends at a rate reset in March 2011 of 6.12%. Dividends ceased accumulating on the stock upon payment of the redemption price, thus the rate was not reset in March 2014.

Equity

Equity	12 Months Ended
	Dec. 31, 2014
Stockholders' Equity Note [Abstract]
Equity	EQUITY
	Issuance of Common Stock
	DOMINION
	Dominion maintains Dominion Direct® and a number of employee savings plans through which contributions may be invested in Dominion's common stock. These shares may either be newly issued or purchased on the open market with proceeds contributed to these plans. In January 2014, Dominion began purchasing its common stock on the open market for these plans. In April 2014, Dominion began issuing new common shares for these direct stock purchase plans.
	During 2014, Dominion issued approximately 3.8 million shares of common stock through various programs.  Dominion received cash proceeds of $205 million from the issuance of 2.9 million of such shares through Dominion Direct and employee savings plans.
	In December 2014, Dominion filed an SEC shelf registration for the sale of debt and equity securities including the ability to sell common stock through an at-the-market program. Also in December 2014, Dominion entered into four separate sales agency agreements to effect sales under the program and pursuant to which it may offer from time to time up to $500 million aggregate amount of its common stock. Sales of common stock can be made by means of privately negotiated transactions, as transactions on the NYSE at market prices or in such other transactions as are agreed upon by Dominion and the sales agents and in conformance with applicable securities laws. At December 31, 2014, a total of 7 million shares of Dominion's common stock was reserved for issuance in connection with this program. In 2015, Dominion provided sales instructions to one of the sales agents and has issued 2.7 million shares through at-the-market issuances and received cash proceeds of $207 million, net of fees and commissions paid of $2 million. Following these issuances, Dominion has the ability to issue up to $291 million of stock under the 2014 sales agency agreements.
	VIRGINIA POWER
	In 2014, 2013 and 2012, Virginia Power did not issue any shares of its common stock to Dominion.
	DOMINION GAS
	On September 30, 2013, Dominion contributed its wholly-owned subsidiaries DTI, East Ohio and Dominion Iroquois to Dominion Gas in exchange for 100% of its limited liability company membership interests.
	Shares Reserved for Issuance
	At December 31, 2014, Dominion had approximately 56 million shares reserved and available for issuance for Dominion Direct®, employee stock awards, employee savings plans, director stock compensation plans, an at-the-market program, and issuance in connection with stock purchase contracts. See Note 17 for more information.
	Repurchase of Common Stock
	Dominion did not repurchase any shares in 2014 or 2013 and does not plan to repurchase shares during 2015, except for shares tendered by employees to satisfy tax withholding obligations on vested restricted stock, which do not count against its stock repurchase authorization.
	Accumulated Other Comprehensive Income (Loss)
	Presented in the table below is a summary of AOCI by component:
	At December 31,	2014			2013
	(millions)
	Dominion
	Net deferred losses on derivatives-hedging activities, net of tax of $116 and $196	$	(178	)	$	(288	)
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(333) and $(307)	548			474
	Net unrecognized pension and other postretirement benefit costs, net of tax of $530 and $365	(782		)	(510		)
	Other comprehensive loss from equity method investees, net of tax of $3 and $--	(4		)	—
	Total AOCI	$	(416	)	$	(324	)
	Virginia Power
	Net deferred losses on derivatives-hedging activities, net of tax of $4 and $---	$	(7	)	$	—
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(35) and $(30)	57			48
	Total AOCI	$	50		$	48
	Dominion Gas
	Net deferred gains (losses) on derivatives-hedging activities, net of tax of $11 and $(1)	$	(20	)	$	3
	Net unrecognized pension and other postretirement benefit costs, net of tax of $46 and $43	(66		)	(61		)
	Total AOCI	$	(86	)	$	(58	)
	DOMINION
	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			Other comprehensive loss from equity method investees			Total
	(millions)
	Year Ended December 31, 2014
	Beginning balance	$	(288	)	$	474		$	(510	)	$	—		$	(324	)
	Other comprehensive income before reclassifications: gains (losses)	17			128			(305		)	(4		)	(164		)
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	93			(54		)	33			—			72
	Net current period other comprehensive income (loss)	110			74			(272		)	(4		)	(92		)
	Ending balance	$	(178	)	$	548		$	(782	)	$	(4	)	$	(416	)
	Year Ended December 31, 2013
	Beginning balance	$	(122	)	$	326		$	(1,081	)	$	—		$	(877	)
	Other comprehensive income before reclassifications: gains (losses)	(243		)	203			516			—			476
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	77			(55		)	55			—			77
	Net current period other comprehensive income (loss)	(166		)	148			571			—			553
	Ending balance	$	(288	)	$	474		$	(510	)	$	—		$	(324	)
	(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)
	Year Ended December 31, 2014
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	130		Operating revenue
		13			Purchased gas
		(7		)	Electric fuel and other energy-related purchases
	Interest rate contracts	16			Interest and related charges
	Total	152
	Tax	(59		)	Income tax expense
	Total, net of tax	$	93
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(100	)	Other income
	Impairment	13			Other income
Total	(87		)
Tax	33			Income tax expense
Total, net of tax	$	(54	)
Unrecognized pension and other postretirement benefit costs:
Prior-service costs (credits)	$	(12	)	Other operations and maintenance
Actuarial losses	69			Other operations and maintenance
Total	57
Tax	(24		)	Income tax expense
Total, net of tax	$	33
Year Ended December 31, 2013
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	58		Operating revenue
	47			Purchased gas
	10			Electric fuel and other energy-related purchases
Interest rate contracts	15			Interest and related charges
Total	130
Tax	(53		)	Income tax expense
Total, net of tax	$	77
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(98	)	Other income
Impairment	8			Other income
Total	(90		)
Tax	35			Income tax expense
Total, net of tax	$	(55	)
Unrecognized pension and other postretirement benefit costs:
Prior-service costs (credits)	$	(8	)	Other operations and maintenance
Actuarial losses	102			Other operations and maintenance
Total	94
Tax	(39		)	Income tax expense
Total, net of tax	$	55
VIRGINIA POWER
The following table presents Virginia Power’s changes in AOCI by component, net of tax:
	Deferred gains and losses on derivatives-hedging activities			Unrealized gains and losses on investment securities			Total
(millions)
Year Ended December 31, 2014
Beginning balance	$	—		$	48		$	48
Other comprehensive income before reclassifications: gains (losses)	(4		)	15			11
Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	(3		)	(6		)	(9		)
Net current period other comprehensive income (loss)	(7		)	9			2
Ending balance	$	(7	)	$	57		$	50
Year Ended December 31, 2013
Beginning balance	$	(6	)	$	31		$	25
Other comprehensive income before reclassifications: gains (losses)	6			20			26
Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	—			(3		)	(3		)
Net current period other comprehensive income (loss)	6			17			23
Ending balance	$	—		$	48		$	48
(1) See table below for details about these reclassifications.
The following table presents Virginia Power’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)
Year Ended December 31, 2014
(Gains) losses on cash flow hedges:
Commodity contracts	$	(5	)	Electric fuel and other energy-related purchases
Interest rate contracts	—			Interest and related charges
Total	(5		)
Tax	2			Income tax expense
Total, net of tax	$	(3	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(10	)	Other income
Total	(10		)
Tax	4			Income tax expense
Total, net of tax	$	(6	)
Year Ended December 31, 2013
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(6	)	Other income
Impairment	1			Other income
Total	(5		)
Tax	2			Income tax expense
Total, net of tax	$	(3	)
DOMINION GAS
The following table presents Dominion Gas' changes in AOCI by component, net of tax:
	Deferred gains and losses on derivatives-hedging activities			Unrecognized pension and other postretirement benefit costs			Total
(millions)
Year Ended December 31, 2014
Beginning balance	$	3		$	(61	)	$	(58	)
Other comprehensive income before reclassifications: gains (losses)	(31		)	(10		)	(41		)
Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	8			5			13
Net current period other comprehensive income (loss)	(23		)	(5		)	(28		)
Ending balance	$	(20	)	$	(66	)	$	(86	)
Year Ended December 31, 2013
Beginning balance	$	(47	)	$	(93	)	$	(140	)
Other comprehensive income before reclassifications: gains (losses)	39			26			65
Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	11			6			17
Net current period other comprehensive income (loss)	50			32			82
Ending balance	$	3		$	(61	)	$	(58	)
(1) See table below for details about these reclassifications.
The following table presents Dominion Gas' reclassifications out of AOCI by component:
Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Year Ended December 31, 2014
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(2	)	Operating revenue
	14			Purchased gas
	1			Interest and related charges
Total	13
Tax	(5		)	Income tax expense
Total, net of tax	$	8
Unrecognized pension and other postretirement benefit costs:
Prior service costs	$	1		Other operations and maintenance
Actuarial losses	7			Other operations and maintenance
Total	8
Tax	(3		)	Income tax expense
Total, net of tax	$	5
Year Ended December 31, 2013
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	2		Operating revenue
	14			Purchased gas
Total	16
Tax	(5		)	Income tax expense
Total, net of tax	$	11
Unrecognized pension and other postretirement benefit costs:
Prior service costs	$	1		Other operations and maintenance
Actuarial losses	9			Other operations and maintenance
Total	10
Tax	(4		)	Income tax expense
Total, net of tax	$	6
Stock-Based Awards
The 2005 and 2014 Incentive Compensation Plans permit stock-based awards that include restricted stock, performance grants, goal-based stock, stock options, and stock appreciation rights. The Non-Employee Directors Compensation Plan permits grants of restricted stock and stock options. Under provisions of these plans, employees and non-employee directors may be granted options to purchase common stock at a price not less than its fair market value at the date of grant with a maximum term of eight years. Option terms are set at the discretion of the CGN Committee of the Board of Directors or the Board of Directors itself, as provided under each plan. At December 31, 2014, approximately 31 million shares were available for future grants under these plans.
Dominion measures and recognizes compensation expense relating to share-based payment transactions over the vesting period based on the fair value of the equity or liability instruments issued. Dominion's results for the years ended December 31, 2014, 2013 and 2012 include $39 million, $31 million, and $25 million, respectively, of compensation costs and $14 million, $11 million, and $8 million, respectively of income tax benefits related to Dominion's stock-based compensation arrangements. Stock-based compensation cost is reported in other operations and maintenance expense in Dominion's Consolidated Statements of Income. Excess tax benefits are classified as a financing cash flow. During the years ended December 31, 2014, 2013, and 2012, Dominion realized less than $1 million, less than $1 million and $10 million, respectively, of excess tax benefits from the vesting of restricted stock awards and exercise of stock options.
Restricted Stock
Restricted stock grants are made to officers under Dominion's LTIP and may also be granted to certain key non-officer employees from time to time. The fair value of Dominion's restricted stock awards is equal to the closing price of Dominion's stock on the date of grant. New shares are issued for restricted stock awards on the date of grant and generally vest over a three-year service period. The following table provides a summary of restricted stock activity for the years ended December 31, 2014, 2013 and 2012:
	Shares		Weighted
			- average
			Grant Date
			Fair Value
	(thousands)
Nonvested at December 31, 2011	1,301		$	37.37
Granted	390		51.14
Vested	(596	)	33.31
Cancelled and forfeited	(10	)	42.99
Nonvested at December 31, 2012	1,085		$	44.46
Granted	312		54.7
Vested	(356	)	39
Cancelled and forfeited	(34	)	51.11
Nonvested at December 31, 2013	1,007		$	49.35
Granted	354		67.98
Vested	(278	)	44.5
Cancelled and forfeited	(18	)	53.61
Nonvested at December 31, 2014	1,065		$	56.74
As of December 31, 2014, unrecognized compensation cost related to nonvested restricted stock awards totaled $27 million and is expected to be recognized over a weighted-average period of 1.8 years. The fair value of restricted stock awards that vested was $19 million, $20 million, and $30 million in 2014, 2013 and 2012, respectively. Employees may elect to have shares of restricted stock withheld upon vesting to satisfy tax withholding obligations. The number of shares withheld will vary for each employee depending on the vesting date fair market value of Dominion stock and the applicable federal, state and local tax withholding rates.
Goal-Based Stock
Goal-based stock awards are granted under Dominion's LTIP to officers who have not achieved a certain targeted level of share ownership, in lieu of cash-based performance grants. Goal-based stock awards may also be made to certain key non-officer employees from time to time. Current outstanding goal-based shares include awards granted to officers in February 2013 and February 2014.
The issuance of awards is based on the achievement of two performance metrics during a two-year period: TSR relative to that of companies listed as members of the Philadelphia Utility Index as of the end of the performance period and ROIC. The actual number of shares issued will vary between zero and 200% of targeted shares depending on the level of performance metrics achieved. The fair value of goal-based stock is equal to the closing price of Dominion's stock on the date of grant. Goal-based stock awards granted to key non-officer employees convert to restricted stock at the end of the two-year performance period and generally vest three years from the original grant date. Awards to officers vest at the end of the two-year performance period. All goal-based stock awards are settled by issuing new shares.
The following table provides a summary of goal-based stock activity for the years ended December 31, 2014, 2013 and 2012:
	Targeted		Weighted
	Number of		- average
	Shares		Grant
			Date Fair
			Value
	(thousands)
Nonvested at December 31, 2011	12		$	39.19
Granted	1		52.48
Vested	(9	)	37.46
Nonvested at December 31, 2012	4		$	45.6
Granted	4		54.17
Vested	(2	)	43.54
Cancelled and forfeited	(1	)	43.54
Nonvested at December 31, 2013	5		$	53.85
Granted	13		68.83
Vested	(1	)	52.48
Nonvested at December 31, 2014	17		$	65.15
At December 31, 2014, the targeted number of shares expected to be issued under the February 2013 and February 2014 awards was approximately 17 thousand. In January 2015, the CGN Committee determined the actual performance against metrics established for the February 2013 awards with a performance period that ended December 31, 2014. Based on that determination, the total number of shares to be issued under the February 2013 goal-based stock awards was approximately 7 thousand.
As of December 31, 2014, unrecognized compensation cost related to nonvested goal-based stock awards was not material.
Cash-Based Performance Grants
Cash-based performance grants are made to Dominion's officers under Dominion's LTIP. The actual payout of cash-based performance grants will vary between zero and 200% of the targeted amount based on the level of performance metrics achieved.
In February 2011, a cash-based performance grant was made to officers. A portion of the grant, representing $6 million was paid in December 2012, based on the achievement of two performance metrics during 2011 and 2012: ROIC and TSR relative to that of a peer group of companies. The total amount of the award under the grant was $8 million and the remaining $2 million of the grant was paid in February 2013.
In February 2012, a cash-based performance grant was made to officers. A portion of the grant, representing the initial payout of $8 million was paid in December 2013, based on the achievement of two performance metrics during 2012 and 2013: TSR relative to that of companies listed as members of the Philadelphia Utility Index as of the end of the performance period and ROIC. The total amount of the award under the grant was $12 million and the remaining portion of the grant was paid in January 2014.
In February 2013, a cash-based performance grant was made to officers. A portion of the grant, representing the initial payout of $14 million was paid in December 2014, based on the achievement of two performance metrics during 2013 and 2014: TSR relative to that of companies listed as members of the Philadelphia Utility Index as of the end of the performance period and ROIC. The total expected award under the grant is $21 million and the remaining portion of the grant is expected to be paid by March 15, 2015. At December 31, 2014, a liability of $7 million had been accrued for the remaining portion of the award.
In February 2014, a cash-based performance grant was made to officers. Payout of the performance grant is expected to occur by March 15, 2016 based on the achievement of two performance metrics during 2014 and 2015: TSR relative to that of companies listed as members of the Philadelphia Utility Index as of the end of the performance period and ROIC. At December 31, 2014, the targeted amount of the grant was $13 million and a liability of $3 million had been accrued for this award.

Dividend_Restrictions

Dividend Restrictions	12 Months Ended
	Dec. 31, 2014
Disclosure of Restrictions on Dividends, Loans and Advances Disclosure [Abstract]
Dividend Restrictions	DIVIDEND RESTRICTIONS
	The Virginia Commission may prohibit any public service company, including Virginia Power, from declaring or paying a dividend to an affiliate if found to be detrimental to the public interest. At December 31, 2014, the Virginia Commission had not restricted the payment of dividends by Virginia Power.
	The Ohio Commission may prohibit any public service company, including East Ohio, from declaring or paying a dividend to an affiliate if found to be detrimental to the public interest. At December 31, 2014, the Ohio Commission had not restricted the payment of dividends by East Ohio.
	Certain agreements associated with the Companies' credit facilities contain restrictions on the ratio of debt to total capitalization. These limitations did not restrict the Companies' ability to pay dividends or receive dividends from their subsidiaries at December 31, 2014.
	See Note 17 for a description of potential restrictions on dividend payments by Dominion in connection with the deferral of interest payments on junior subordinated notes and equity units, initially in the form of corporate units.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2014
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Employee Benefit Plans	EMPLOYEE BENEFIT PLANS
	Dominion and Dominion Gas - Defined Benefit Plans
	Dominion provides certain retirement benefits to eligible active employees, retirees and qualifying dependents. Dominion Gas participates in a number of the Dominion-sponsored retirement plans. Under the terms of its benefit plans, Dominion reserves the right to change, modify or terminate the plans. From time to time in the past, benefits have changed, and some of these changes have reduced benefits.
	Dominion maintains qualified noncontributory defined benefit pension plans covering virtually all employees. Retirement benefits are based primarily on years of service, age and the employee's compensation. Dominion's funding policy is to contribute annually an amount that is in accordance with the provisions of ERISA. The pension program also provides benefits to certain retired executives under a company-sponsored nonqualified employee benefit plan. The nonqualified plan is funded through contributions to a grantor trust. Dominion also provides retiree healthcare and life insurance benefits with annual employee premiums based on several factors such as age, retirement date and years of service.
	Pension benefits for Dominion Gas employees not represented by collective bargaining units are covered by the Dominion Pension Plan, a defined benefit pension plan sponsored by Dominion that provides benefits to multiple Dominion subsidiaries. Pension benefits for Dominion Gas employees represented by collective bargaining units are covered by separate pension plans for East Ohio and, for DTI, a plan that provides benefits to employees of both DTI and Hope. Employee compensation is the basis for allocating pension costs and obligations between DTI and Hope and determining East Ohio's share of total pension costs.
	Retiree healthcare and life insurance benefits for Dominion Gas employees not represented by collective bargaining units are covered by the Dominion Retiree Health and Welfare Plan, a plan sponsored by Dominion that provides certain retiree healthcare and life insurance benefits to multiple Dominion subsidiaries. Retiree healthcare and life insurance benefits for Dominion Gas employees represented by collective bargaining units are covered by separate other postretirement benefit plans for East Ohio and, for DTI, a plan that provides benefits to both DTI and Hope. Employee headcount is the basis for allocating other postretirement benefit costs and obligations between DTI and Hope and determining East Ohio's share of total other postretirement benefit costs.
	Pension and other postretirement benefit costs are affected by employee demographics (including age, compensation levels and years of service), the level of contributions made to the plans and earnings on plan assets. These costs may also be affected by changes in key assumptions, including expected long-term rates of return on plan assets, discount rates, healthcare cost trend rates, mortality rates and the rate of compensation increases.
	Dominion uses December 31 as the measurement date for all of its employee benefit plans, including those in which Dominion Gas participates. Dominion uses the market-related value of pension plan assets to determine the expected return on plan assets, a component of net periodic pension cost, for all pension plans, including those in which Dominion Gas participates. The market-related value recognizes changes in fair value on a straight-line basis over a four-year period, which reduces year-to-year volatility. Changes in fair value are measured as the difference between the expected and actual plan asset returns, including dividends, interest and realized and unrealized investment gains and losses. Since the market-related value recognizes changes in fair value over a four-year period, the future market-related value of pension plan assets will be impacted as previously unrecognized changes in fair value are recognized.
	Dominion's pension and other postretirement benefit plans hold investments in trusts to fund employee benefit payments. Aggregate actual returns for Dominion's pension and other postretirement plan assets were $706 million in 2014 and $959 million in 2013, versus expected returns of $610 million and $554 million, respectively. Aggregate actual returns for pension and other postretirement benefit plan assets for Dominion Gas employees represented by collective bargaining units were $157 million in 2014 and $214 million in 2013, versus expected returns of $138 million and $125 million, respectively. Differences between actual and expected returns on plan assets are accumulated and amortized during future periods. As such, any investment-related declines in these trusts will result in future increases in the net periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of cash to be contributed to the employee benefit plans.
	The Medicare Act introduced a federal subsidy to sponsors of retiree healthcare benefit plans that provide a prescription drug benefit that is at least actuarially equivalent to Medicare Part D. Dominion determined that the prescription drug benefit offered under its other postretirement benefit plans is at least actuarially equivalent to Medicare Part D. Dominion received a federal subsidy of $4 million and $5 million for 2014 and 2013, respectively. Dominion Gas received a federal subsidy of $1 million for each of 2014 and 2013. Effective January 1, 2013, Dominion changed its method of receiving the subsidy under Medicare Part D for retiree prescription drug coverage from the Retiree Drug Subsidy to the EGWP. This change reduced other postretirement benefit costs by approximately $20 million annually beginning in 2012. As a result of the adoption of the EGWP, Dominion will begin to receive an increased level of Medicare Part D subsidies, in the form of reduced costs rather than a direct reimbursement, over the next few years.
	In October 2014, the Society of Actuaries published new mortality tables and mortality improvement scales. Such tables and scales are used to develop mortality assumptions for use in determining pension and other postretirement benefit liabilities and expense. Following evaluation of the new tables, Dominion changed its assumption for mortality rates to reflect a generational improvement scale. As a result of this change in assumption, at December 31, 2014 Dominion and Dominion Gas (for employees represented by collective bargaining units) increased their pension benefit obligations by $131 million and $10 million, respectively, and increased their accumulated postretirement benefit obligations by $32 million and $7 million, respectively. This change is expected to increase net periodic benefit cost for Dominion and Dominion Gas (for employees represented by collective bargaining units) by approximately $25 million and $3 million, respectively, for 2015.
	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. For Dominion Gas employees represented by collective bargaining units, the remeasurement resulted in a reduction in the pension benefit obligation of approximately $28 million and a reduction in the accumulated postretirement benefit obligation of approximately $9 million. The impact of the remeasurement on net periodic benefit (credit) cost was recognized prospectively from the remeasurement date and reduced net periodic benefit cost for 2013 by approximately $36 million, excluding the impacts of curtailments, and for Dominion Gas employees represented by collective bargaining units by approximately $2 million. The discount rate used for the remeasurement was 4.80% for the pension plans and 4.70% for the other postretirement benefit plans. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2012.
	In the fourth quarter of 2013, Dominion remeasured its other postretirement benefit plans as a result of a plan amendment that changed medical coverage for certain Medicare-eligible retirees effective April 2014. The remeasurement resulted in a reduction in the accumulated postretirement benefit obligation of approximately $220 million. The impact of the remeasurement on net periodic benefit (credit) cost was recognized prospectively from the remeasurement date and reduced net periodic benefit cost for 2013 by approximately $8 million. The amendment is expected to reduce net periodic benefit cost by $40 million to $60 million for each of the next five years. The discount rate used for the remeasurement was 4.80%. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2012.
	In the third quarter of 2014, East Ohio remeasured its other postretirement benefit plan as a result of an amendment that changed medical coverage upon the attainment of age 65 for certain future retirees effective January 1, 2016. For employees represented by collective bargaining units, the remeasurement resulted in an increase in the accumulated postretirement benefit obligation of approximately $22 million. The impact of the remeasurement on net periodic benefit credit was recognized prospectively from the remeasurement date and reduced net periodic benefit credit for 2014, for employees represented by collective bargaining units, by less than $1 million. The discount rate used for the remeasurement was 4.20% and the expected long-term rate of return used was 8.50%. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2013.
	Funded Status
	The following table summarizes the changes in pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans' funded status for Dominion and Dominion Gas (for employees represented by collective bargaining units):
		Pension Benefits						Other Postretirement
								Benefits
	Year Ended December 31,	2014			2013			2014			2013
	(millions, except percentages)
	DOMINION
	Changes in benefit obligation:
	Benefit obligation at beginning of year	$	5,625		$	6,125		$	1,360		$	1,719
	Service cost	114			131			32			43
	Interest cost	290			271			67			73
	Benefits paid	(236		)	(229		)	(78		)	(75		)
	Actuarial (gains) losses during the year	887			(650		)	177			(170		)
	Plan amendments(1)	—			1			9			(220		)
	Settlements and curtailments(2)	(13		)	(24		)	—			(16		)
	Special termination benefits	—			—			—			1
	Medicare Part D reimbursement	—			—			4			5
	Benefit obligation at end of year	$	6,667		$	5,625		$	1,571		$	1,360
	Changes in fair value of plan assets:
	Fair value of plan assets at beginning of year	$	6,113		$	5,553		$	1,315		$	1,156
	Actual return on plan assets	601			781			105			178
	Employer contributions	15			8			12			12
	Benefits paid	(236		)	(229		)	(30		)	(31		)
	Settlements(2)	(13		)	—			—			—
	Fair value of plan assets at end of year	$	6,480		$	6,113		$	1,402		$	1,315
	Funded status at end of year	$	(187	)	$	488		$	(169	)	$	(45	)
	Amounts recognized in the Consolidated Balance Sheets at December 31:
	Noncurrent pension and other postretirement benefit assets	$	946		$	913		$	10		$	29
	Other current liabilities	(13		)	(15		)	(3		)	(3		)
	Noncurrent pension and other postretirement benefit liabilities	(1,120		)	(410		)	(176		)	(71		)
	Net amount recognized	$	(187	)	$	488		$	(169	)	$	(45	)
	Significant assumptions used to determine benefit obligations as of December 31:
	Discount rate(3)	4.4		%	5.20%/5.30%			4.4		%	5.00%/5.10%
	Weighted average rate of increase for compensation	4.22		%	4.21		%	4.22		%	4.22		%
	Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	7.75		%
	DOMINION GAS
	Changes in benefit obligation:
	Benefit obligation at beginning of year	$	563		$	607		$	269		$	287
	Service cost	12			13			6			7
	Interest cost	28			27			13			12
	Benefits paid	(29		)	(27		)	(16		)	(17		)
	Actuarial (gains) losses during the year	64			(57		)	38			(21		)
	Plan amendments	—			—			9			—
	Medicare Part D reimbursement	—			—			1			1
	Benefit obligation at end of year	$	638		$	563		$	320		$	269
	Changes in fair value of plan assets:
	Fair value of plan assets at beginning of year	$	1,403		$	1,254		$	273		$	242
	Actual return on plan assets	136			176			21			38
	Employer contributions	—			—			10			10
	Benefits paid	(29		)	(27		)	(16		)	(17		)
Fair value of plan assets at end of year	$	1,510		$	1,403		$	288		$	273
Funded status at end of year	$	872		$	840		$	(32	)	$	4
Amounts recognized in the Consolidated Balance Sheets at December 31:
Noncurrent pension and other postretirement benefit assets	$	872		$	840		$	—		$	19
Noncurrent pension and other postretirement benefit liabilities(4)	—			—			(32		)	(15		)
Net amount recognized	$	872		$	840		$	(32	)	$	4
Significant assumptions used to determine benefit obligations as of December 31:
Discount rate	4.4		%	5.2		%	4.4		%	5		%
Weighted average rate of increase for compensation	3.93		%	3.93		%	3.93		%	3.93		%
Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	7.75		%
-1	2013 other postretirement benefits amount relates to a plan amendment that changed medical coverage for certain Medicare-eligible retirees.
-2	2014 amounts relate primarily to a settlement charge for certain executives. 2013 amounts relate primarily to the decommissioning of Kewaunee.
-3	2013 pension and other postretirement benefits discount rates: 5.20% and 5.00% for the gas union plans and 5.30% and 5.10% for the nonunion and other union plans, respectively.
-4	Reflected in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.
The ABO for all of Dominion's defined benefit pension plans was $6.0 billion and $5.1 billion at December 31, 2014 and 2013, respectively. The ABO for the defined benefit pension plans covering Dominion Gas employees represented by collective bargaining units was $604 million and $534 million at December 31, 2014 and 2013, respectively.
Under its funding policies, Dominion evaluates plan funding requirements annually, usually in the fourth quarter after receiving updated plan information from its actuary. Based on the funded status of each plan and other factors, Dominion determines the amount of contributions for the current year, if any, at that time. During 2014, Dominion and Dominion Gas made no contributions to the qualified defined benefit pension plans and no contributions are currently expected in 2015. In July 2012, the MAP 21 Act was signed into law. This Act includes an increase in the interest rates used to determine plan sponsors' pension contributions for required funding purposes. In 2014, the HATFA of 2014 was signed into law. Similar to the MAP 21 Act, the HATFA of 2014 adjusts the rules for calculating interest rates used in determining funding obligations. It is estimated that the new interest rates will reduce required pension contributions through 2019. Dominion believes that required pension contributions will rise subsequent to 2019, resulting in an estimated $200 million reduction in net cumulative required contributions over a 10-year period.
Certain regulatory authorities have held that amounts recovered in utility customers' rates for other postretirement benefits, in excess of benefits actually paid during the year, must be deposited in trust funds dedicated for the sole purpose of paying such benefits. Accordingly, certain of Dominion's subsidiaries, including Dominion Gas, fund other postretirement benefit costs through VEBAs. Dominion's remaining subsidiaries do not prefund other postretirement benefit costs but instead pay claims as presented. Dominion’s contributions to VEBAs, all of which pertained to Dominion Gas employees, totaled $12 million for both 2014 and 2013, and Dominion expects to contribute approximately $12 million to the Dominion VEBAs in 2015, all of which pertains to Dominion Gas employees.
Dominion and Dominion Gas do not expect any pension or other postretirement plan assets to be returned during 2015.
The following table provides information on the benefit obligations and fair value of plan assets for plans with a benefit obligation in excess of plan assets for Dominion and Dominion Gas (for employees represented by collective bargaining units):
	Pension Benefits						Other Postretirement
							Benefits
As of December 31,	2014			2013			2014			2013
(millions)
DOMINION
Benefit obligation	$	5,970		$	4,978		$	1,564		$	1,233
Fair value of plan assets	4,838			4,553			1,385			1,158
DOMINION GAS
Benefit obligation	$	—		$	—		$	320		$	147
Fair value of plan assets	—			—			288			132
The following table provides information on the ABO and fair value of plan assets for Dominion’s pension plans with an ABO in excess of plan assets:
As of December 31,	2014			2013
(millions)
Accumulated benefit obligation	$	5,370		$	114
Fair value of plan assets	4,838			—
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans:
	Estimated Future Benefit Payments
	Pension Benefits			Other  Postretirement Benefits
(millions)
DOMINION
2015	$	272		$	91
2016	284			94
2017	300			98
2018	320			101
2019	333			102
2020-2024	1,925			523
DOMINON GAS
2015	$	34		$	18
2016	35			19
2017	37			20
2018	38			21
2019	39			22
2020-2024	204			111
Plan Assets
Dominion's overall objective for investing its pension and other postretirement plan assets is to achieve appropriate long-term rates of return commensurate with prudent levels of risk. As a participating employer in various pension plans sponsored by Dominion, Dominion Gas is subject to Dominion's investment policies for such plans. To minimize risk, funds are broadly diversified among asset classes, investment strategies and investment advisors. The strategic target asset allocations for Dominion's pension funds are 28% U.S. equity, 18% non-U.S. equity, 33% fixed income, 3% real estate and 18% other alternative investments. U.S. equity includes investments in large-cap, mid-cap and small-cap companies located in the United States. Non-U.S. equity includes investments in large-cap and small-cap companies located outside of the United States including both developed and emerging markets. Fixed income includes corporate debt instruments of companies from diversified industries and U.S. Treasuries. The U.S. equity, non-U.S. equity and fixed income investments are in individual securities as well as mutual funds. Real estate includes equity REITs and investments in partnerships. Other alternative investments include partnership investments in private equity, debt and hedge funds that follow several different strategies.
Dominion also utilizes common/collective trust funds as an investment vehicle for its defined benefit plans. A common/collective trust fund is a pooled fund operated by a bank or trust company for investment of the assets of various organizations and individuals in a well-diversified portfolio. Common/collective trust funds are funds of grouped assets that follow various investment strategies.
Strategic investment policies are established for Dominion's prefunded benefit plans based upon periodic asset/liability studies. Factors considered in setting the investment policy include employee demographics, liability growth rates, future discount rates, the funded status of the plans and the expected long-term rate of return on plan assets. Deviations from the plans' strategic allocation are a function of Dominion's assessments regarding short-term risk and reward opportunities in the capital markets and/or short-term market movements which result in the plans' actual asset allocations varying from the strategic target asset allocations. Through periodic rebalancing, actual allocations are brought back in line with the target. Future asset/liability studies will focus on strategies to further reduce pension and other postretirement plan risk, while still achieving attractive levels of returns. Financial derivatives may be used to obtain or manage market exposures and to hedge assets and liabilities.
For fair value measurement policies and procedures related to pension and other postretirement benefit plan assets, see Note 6.
The fair values of Dominion's and Dominion Gas’ (for employees represented by collective bargaining units) pension plan assets by asset category are as follows:
	Fair Value Measurements
	Pension Plans
At December 31,	2014												2013
	Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
(millions)
DOMINION
Cash equivalents	$	13		$	25		$	—		$	38		$	53		$	126		$	—		$	179
U.S. equity:
Large Cap	1,313			—			—			1,313			1,220			—			—			1,220
Other	530			—			—			530			514			—			—			514
Non-U.S. equity:
Large Cap	234			—			—			234			308			—			—			308
Other	403			—			—			403			391			—			—			391
Common/collective trust funds(1)	—			1,595			—			1,595			—			1,387			—			1,387
Fixed income:
Corporate debt instruments	45			666			—			711			43			451			—			494
U.S. Treasury securities and agency debentures	74			342			—			416			2			229			—			231
State and municipal	10			60			—			70			69			107			—			176
Other securities	6			80			—			86			7			50			—			57
Real estate:
REITs	40			—			—			40			32			—			—			32
Partnerships	—			—			209			209			—			—			227			227
Other alternative investments:
Private equity	—			—			518			518			—			—			530			530
Debt	—			—			144			144			—			—			180			180
Hedge funds	—			—			162			162			—			—			187			187
Total(2)	$	2,668		$	2,768		$	1,033		$	6,469		$	2,639		$	2,350		$	1,124		$	6,113
DOMINION GAS
Cash equivalents	$	3		$	6		$	—		$	9		$	12		$	29		$	—		$	41
U.S. equity:
Large Cap	306			—			—			306			280			—			—			280
Other	124			—			—			124			118			—			—			118
Non-U.S. equity:
Large Cap	54			—			—			54			72			—			—			72
Other	94			—			—			94			90			—			—			90
Common/collective trust funds(3)	—			372			—			372			—			318			—			318
Fixed income:
Corporate debt instruments	11			155			—			166			10			103			—			113
U.S. Treasury securities and agency debentures	17			80			—			97			1			52			—			53
State and municipal	2			14			—			16			16			24			—			40
Other securities	1			19			—			20			2			11			—			13
Real estate:
REITs	9			—			—			9			7			—			—			7
Partnerships	—			—			48			48			—			—			52			52
Other alternative investments:
Private equity	—			—			121			121			—			—			122			122
Debt	—			—			34			34			—			—			41			41
Hedge funds	—			—			38			38			—			—			43			43
Total(4)	$	621		$	646		$	241		$	1,508		$	608		$	537		$	258		$	1,403
-1	Common/Collective Trust Funds include $360 million and $560 million of John Hancock insurance contracts held at December 31, 2014 and 2013, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
-2	Includes net assets related to pending sales of securities of $31 million, net accrued income of $18 million, and excludes net assets related to pending purchases of securities of $38 million at December 31, 2014.
-3	See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
-4	Includes net assets related to pending sales of securities of $7 million, net accrued income of $4 million, and excludes net assets related to pending purchases of securities of $9 million at December 31, 2014.
The fair values of Dominion's and Dominion Gas’ (for employees represented by collective bargaining units) other postretirement plan assets by asset category are as follows:
	Fair Value Measurements
	Other Postretirement Plans
At December 31,	2014												2013
	Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
(millions)
DOMINION
Cash equivalents	$	1		$	7		$	—		$	8		$	3		$	14		$	—		$	17
U.S. equity:
Large Cap	514			—			—			514			472			—			—			472
Other	28			—			—			28			26			—			—			26
Non-U.S. equity:
Large Cap	102			—			—			102			111			—			—			111
Other	21			—			—			21			20			—			—			20
Common/collective trust funds(1)	—			555			—			555			—			502			—			502
Fixed income:
Corporate debt instruments	3			35			—			38			2			23			—			25
U.S. Treasury securities and agency debentures	4			18			—			22			—			12			—			12
State and municipal	1			3			—			4			4			5			—			9
Other securities	—			4			—			4			—			3			—			3
Real estate:
REITs	2			—			—			2			2			—			—			2
Partnerships	—			—			19			19			—			—			19			19
Other alternative investments:
Private equity	—			—			58			58			—			—			60			60
Debt	—			—			18			18			—			—			27			27
Hedge funds	—			—			9			9			—			—			10			10
Total	$	676		$	622		$	104		$	1,402		$	640		$	559		$	116		$	1,315
DOMINION GAS
Cash equivalents	$	—		$	2		$	—		$	2		$	—		$	3		$	—		$	3
U.S. equity-Large Cap	113			—			—			113			104			—			—			104
Non-U.S. equity-Large Cap	26			—			—			26			26			—			—			26
Common/collective trust funds(2)	—			129			—			129			—			119			—			119
Real estate - partnerships	—			—			2			2			—			—			2			2
Other alternative investments:
Private equity	—			—			12			12			—			—			12			12
Debt	—			—			4			4			—			—			7			7
Total	$	139		$	131		$	18		$	288		$	130		$	122		$	21		$	273
(1) Common/Collective Trust Funds include $19 million and $29 million of John Hancock insurance contracts held at December 31, 2014 and 2013, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
-2	See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
The following table presents the changes in pension and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category for Dominion and Dominion Gas (for employees represented by collective bargaining units):
	Fair Value Measurements using Significant Unobservable Inputs (Level 3)
	Pension Plans															Other Postretirement Plans
	Real Estate			Private Equity			Debt			Hedge Funds			Total			Real Estate			Private Equity			Debt			Hedge Funds			Total
DOMINION
Balance at December 31, 2011	$	304		$	448		$	243		$	290		$	1,285		$	24		$	63		$	36		$	14		$	137
Actual return on plan assets:
Relating to assets still held at the reporting date	21			46			17			21			105			1			3			4			1			9
Relating to assets sold during the period	(8		)	(41		)	(11		)	(2		)	(62		)	—			(1		)	—			—			(1		)
Purchases	35			79			15			—			129			2			6			1			—			9
Sales	(31		)	(76		)	(72		)	(88		)	(267		)	(3		)	(13		)	(10		)	(4		)	(30		)
Balance at December 31, 2012	$	321		$	456		$	192		$	221		$	1,190		$	24		$	58		$	31		$	11		$	124
Actual return on plan assets:
Relating to assets still held at the reporting date	15			98			32			21			166			(2		)	6			3			1			8
Relating to assets sold during the period	(36		)	(48		)	(34		)	(4		)	(122		)	1			3			—			1			5
Purchases	6			115			32			—			153			1			7			2			—			10
Sales	(79		)	(91		)	(42		)	(51		)	(263		)	(5		)	(14		)	(9		)	(3		)	(31		)
Balance at December 31, 2013	$	227		$	530		$	180		$	187		$	1,124		$	19		$	60		$	27		$	10		$	116
Actual return on plan assets:
Relating to assets still held at the reporting date	40			70			12			4			126			4			7			2			—			13
Relating to assets sold during the period	(18		)	(67		)	(26		)	(4		)	(115		)	(1		)	(7		)	(3		)	—			(11		)
Purchases	—			135			10			—			145			—			13			1			—			14
Sales	(40		)	(150		)	(32		)	(25		)	(247		)	(3		)	(15		)	(9		)	(1		)	(28		)
Balance at December 31, 2014	$	209		$	518		$	144		$	162		$	1,033		$	19		$	58		$	18		$	9		$	104
DOMINION GAS
Balance at December 31, 2011	$	68		$	99		$	54		$	64		$	285		$	3		$	15		$	10		$	—		$	28
Actual return on plan assets:
Relating to assets still held at the reporting date	6			12			4			4			26			—			(1		)	(1		)	—			(2		)
Relating to assets sold during the period	(2		)	(9		)	(2		)	—			(13		)	—			2			1			—			3
Purchases	7			17			3			—			27			—			1			—			—			1
Sales	(7		)	(16		)	(16		)	(18		)	(57		)	—			(4		)	(2		)	—			(6		)
Balance at December 31, 2012	$	72		$	103		$	43		$	50		$	268		$	3		$	13		$	8		$	—		$	24
Actual return on plan assets:
Relating to assets still held at the reporting date	4			24			7			5			40			(1		)	2			1			—			2
Relating to assets sold during the period	(8		)	(10		)	(7		)	(1		)	(26		)	—			—			—			—			—
Purchases	1			25			7			—			33			—			1			—			—			1
Sales	(17		)	(20		)	(9		)	(11		)	(57		)	—			(4		)	(2		)	—			(6		)
Balance at December 31, 2013	$	52		$	122		$	41		$	43		$	258		$	2		$	12		$	7		$	—		$	21
Actual return on plan assets:
Relating to assets still held at the reporting date	9			17			4			1			31			—			2			1			—			3
Relating to assets sold during the period	(4		)	(15		)	(6		)	(1		)	(26		)	—			(1		)	(1		)	—			(2		)
Purchases	—			30			2			—			32			—			2			—			—			2
Sales	(9		)	(33		)	(7		)	(5		)	(54		)	—			(3		)	(3		)	—			(6		)
Balance at December 31, 2014	$	48		$	121		$	34		$	38		$	241		$	2		$	12		$	4		$	—		$	18
Investments in Common/Collective Trust Funds in Dominion’s pension and other postretirement plans, including those in which Dominion Gas participates, are stated at fair value as determined by the issuer of the Common/Collective Trust Funds based on the fair value of the underlying investments. The Common/Collective Trusts do not have any unfunded commitments, and do not have any applicable liquidation periods or defined terms/periods to be held. The majority of the Common/Collective Trust Funds have limited withdrawal or redemption rights during the term of the investment. Strategies of the Common/Collective Trust Funds are as follows:
Dominion and Dominion Gas
•	Wells Fargo Closed End Bond Trust-The Fund invests in stocks, bonds or a combination of both. Shares of the Fund are traded on a stock exchange and are subject to market risk like stocks, bonds and mutual funds. The Fund may invest in a less liquid portfolio of stocks and bonds because the fund does not need to sell securities to meet shareholder redemptions as mutual funds in order to keep a percentage of its portfolio in cash to pay back investors who withdraw shares.
•	JPMorgan Core Bond Trust-The Fund seeks to maximize total return by investing primarily in a diversified portfolio of intermediate- and long-term debt securities. The Fund invests primarily in investment-grade bonds; it generally maintains an average weighted maturity between four and 12 years. It may shorten its average weighted maturity if deemed appropriate for temporary defensive purposes.
•	SSgA Russell 2000 Value Index Common Trust-The Fund measures the performance of the small-cap value segment of the U.S. equity universe. The Russell 2000 Value Index is constructed to provide a comprehensive and unbiased barometer for the small-cap value segment. The Index is completely reconstituted annually to ensure larger stocks do not distort the performance and characteristics of the true small-cap opportunity set and that the represented companies continue to reflect value characteristics.
•	NT Common Short-Term Investment Fund-The Fund seeks to maximize current income on cash reserves to the extent consistent with principal preservation and maintenance of liquidity from a portfolio of approved money market instruments with short maturities. Liquidity is emphasized to provide for redemption of units at par on any business day. Principal preservation is a primary objective. Within quality, maturity, and sector diversification guidelines, investments are made in those securities with the most attractive yields.
Dominion
•	SSgA Daily MSCI Emerging Markets Index Non-Lending Fund-The Fund seeks an investment return that approximates as closely as practicable, before expenses, the performance of the MSCI Emerging Markets Index over the long term. The Fund may invest directly or indirectly in securities and other instruments, including in other pooled investment vehicles sponsored or managed by, or otherwise affiliated with the Trustee (State Street Bank and Trust Company).
•	SSgA Daily MSCI ACWI Ex-USA Index Non-Lending Fund-The Fund seeks an investment return that approximates as closely as practicable, before expenses, the performance of the MSCI ACWI Ex-USA Index over the long term. The Fund may invest directly or indirectly in securities and other instruments, including in other pooled investment vehicles sponsored or managed by, or otherwise affiliated with the Trustee (State Street Bank and Trust Company).
•	SSgA S&P 400 MidCap Index - The Fund seeks an investment return that approximates as closely as practicable, before expenses, the performance of its benchmark index (the Index) over the long term.  The S&P MidCap 400 is comprised of approximately 400 U.S. mid-cap securities and accounts for approximately 7% coverage of the U.S. stock market capitalization. SSgA will typically attempt to invest in the equity securities comprising the Index, in approximately the same proportions as they are represented in the Index.
•	JPMorgan Chase Bank U.S. Active Core Plus Equity Fund-The Fund seeks to outperform the S&P 500 Index (the Benchmark), gross of fees, over a market cycle. The Fund invests primarily in a portfolio of long and short positions in equity securities of large and mid capitalization U.S. companies with characteristics similar to those of the Benchmark.
•	Mondrian International Small Cap Equity Fund-The Fund’s investment objective is long-term total return. The Fund primarily invests in equity securities of non-U.S. small capitalization companies that, in the investment manager’s opinion, are undervalued at the time of purchase based on fundamental value analysis employed by the investment manager.
•	NT Collective Russell 2000 Growth Index - The Fund seeks an investment return that approximates the overall performance of the common stocks included in the Russell 2000 Growth Index. The Fund primarily invests in common stocks of one or more companies that are deemed to be representative of the industry diversification of the entire Russell 2000 Growth Index.
•	NT Collective Short-Term Investment Fund - The Fund is composed of high-grade money market instruments with short-term maturities. The Fund's objective is to provide an investment vehicle for cash reserves while offering a competitive rate of return. Liquidity is emphasized to provide for redemption of units on any business day. Principal preservation is also a prime objective. Admissions and withdrawals are made daily. Interest is accrued daily and distributed monthly.
Investments in Group Insurance Annuity Contracts with John Hancock were entered into after 1992 and are stated at fair value based on the fair value of the underlying securities as provided by the managers and include investments in U.S. government securities, corporate debt instruments, and state and municipal debt securities.
Net Periodic Benefit (Credit) Cost
Net periodic benefit (credit) cost is reflected in other operations and maintenance expense in the Consolidated Statements of Income. The components of the provision for net periodic benefit (credit) cost and amounts recognized in other comprehensive income and regulatory assets and liabilities for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans are as follows:
	Pension Benefits									Other Postretirement Benefits
Year Ended December 31,	2014			2013			2012			2014			2013			2012
(millions, except percentages)
DOMINION
Service cost	$	114		$	131		$	116		$	32		$	43		$	44
Interest cost	290			271			268			67			73			79
Expected return on plan assets	(499		)	(462		)	(430		)	(111		)	(92		)	(79		)
Amortization of prior service (credit) cost	3			3			3			(28		)	(15		)	(13		)
Amortization of net actuarial loss	111			165			132			2			7			6
Settlements and curtailments(1)	1			(2		)	—			—			(15		)	(4		)
Special termination benefits	—			—			—			—			1			—
Net periodic benefit (credit) cost	$	20		$	106		$	89		$	(38	)	$	2		$	33
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss	$	784		$	(968	)	$	786		$	183		$	(255	)	$	139
Prior service (credit) cost	—			1			—			9			(215		)	1
Settlements and curtailments(1)	(1		)	(22		)	—			—			(7		)	(2		)
Less amounts included in net periodic benefit cost:
Amortization of net actuarial loss	(111		)	(165		)	(132		)	(2		)	(7		)	(6		)
Amortization of prior service credit (cost)	(3		)	(3		)	(3		)	28			15			13
Total recognized in other comprehensive income and regulatory assets and liabilities	$	669		$	(1,157	)	$	651		$	218		$	(469	)	$	145
Significant assumptions used to determine periodic cost:
Discount rate	5.20% - 5.30%			4.40% - 4.80%			5.5		%	4.20% - 5.10%			4.40% - 4.80%			5.5		%
Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	8.5		%	7.75		%	7.75		%
Weighted average rate of increase for compensation	4.21		%	4.21		%	4.21		%	4.22		%	4.22		%	4.22		%
Healthcare cost trend rate(2)										7		%	7		%	7		%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)(2)										5		%	4.6		%	4.6		%
Year that the rate reaches the ultimate trend rate(2)(3)										2018			2062			2061
DOMINION GAS
Service cost	$	12		$	13		$	11		$	6		$	7		$	7
Interest cost	28			27			28			13			12			14
Expected return on plan assets	(115		)	(106		)	(96		)	(23		)	(19		)	(16		)
Amortization of prior service (credit) cost	1			1			1			(1		)	(3		)	(4		)
Amortization of net actuarial loss	19			26			26			—			2			1
Net periodic benefit (credit) cost	$	(55	)	$	(39	)	$	(30	)	$	(5	)	$	(1	)	$	2
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss	$	43		$	(127	)	$	35		$	40		$	(40	)	$	12
Prior service cost	—			—			—			10			—			—
Less amounts included in net periodic benefit cost:
Amortization of net actuarial loss	(19		)	(26		)	(26		)	—			(2		)	(1		)
Amortization of prior service credit (cost)	(1		)	(1		)	(1		)	1			3			4
Total recognized in other comprehensive income and regulatory assets and liabilities	$	23		$	(154	)	$	8		$	51		$	(39	)	$	15
Significant assumptions used to determine periodic cost:
Discount rate	5.2		%	4.40% - 4.80%			5.5		%	4.20% - 5.00%			4.40% - 4.70%			5.5		%
Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	8.5		%	7.75		%	7.75		%
Weighted average rate of increase for compensation	3.93		%	3.93		%	3.93		%	3.93		%	3.93		%	3.93		%
Healthcare cost trend rate(2)										7		%	7		%	7		%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)(2)										5		%	4.6		%	4.6		%
Year that the rate reaches the ultimate trend rate(2)(3)										2018			2062			2061
-1	2013 amounts relate primarily to the decommissioning of Kewaunee.
-2	Assumptions used to determine net periodic cost for the following year.
-3	The Society of Actuaries model used to determine healthcare cost trend rates was updated in 2014. The new model converges to the ultimate trend rate much more quickly than previous models.
The components of AOCI and regulatory assets and liabilities for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans that have not been recognized as components of net periodic benefit (credit) cost are as follows:
	Pension Benefits						Other Postretirement Benefits
At December 31,	2014			2013			2014			2013
(millions)
DOMINION
Net actuarial (gain) loss	$	2,382		$	1,709		$	139		$	(40	)
Prior service (credit) cost	7			10			(233		)	(271		)
Total(1)	$	2,389		$	1,719		$	(94	)	$	(311	)
DOMINION GAS
Net actuarial loss	$	303		$	279		$	43		$	3
Prior service (credit) cost	1			2			7			(4		)
Total(2)	$	304		$	281		$	50		$	(1	)
-1	As of December 31, 2014, of the $2.4 billion and $(94) million related to pension benefits and other postretirement benefits, $1.4 billion and $(81) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2013, of the $1.7 billion and $(311) million related to pension benefits and other postretirement benefits, $1.0 billion and $(156) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.
-2	As of December 31, 2014, of the $304 million related to pension benefits, $112 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $50 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. As of December 31, 2013, of the $281 million related to pension benefits, $104 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $(1) million related to other postretirement benefits is included entirely in regulatory assets and liabilities.
The following table provides the components of AOCI and regulatory assets and liabilities for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans as of December 31, 2014 that are expected to be amortized as components of net periodic benefit (credit) cost in 2015:
	Pension			Other
	Benefits			Postretirement
				Benefits
(millions)
DOMINION
Net actuarial loss	$	160		$	6
Prior service (credit) cost	2			(27		)
DOMINION GAS
Net actuarial loss	$	20		$	2
Prior service cost	1			—
The expected long-term rates of return on plan assets, discount rates, healthcare cost trend rates and mortality are critical assumptions in determining net periodic benefit (credit) cost. Dominion develops assumptions, which are then compared to the forecasts of an independent investment advisor (except for the expected long-term rates of return) to ensure reasonableness. An internal committee selects the final assumptions used for Dominion's pension and other postretirement plans, including those in which Dominion Gas participates, including discount rates, expected long-term rates of return, healthcare cost trend rates and mortality rates.
Dominion determines the expected long-term rates of return on plan assets for its pension plans and other postretirement benefit plans, including those in which Dominion Gas participates, by using a combination of:
•	Expected inflation and risk-free interest rate assumptions;
•	Historical return analysis to determine long term historic returns as well as historic risk premiums for various asset classes;
•	Expected future risk premiums, asset volatilities and correlations;
•	Forecasts of an independent investment advisor;
•	Forward-looking return expectations derived from the yield on long-term bonds and the expected long-term returns of major stock market indices; and
•	Investment allocation of plan assets.
Dominion determines discount rates from analyses of AA/Aa rated bonds with cash flows matching the expected payments to be made under its plans, including those in which Dominion Gas participates.
Dominion develops its mortality assumption using plan-specific studies and projects mortality improvement using scales developed by the Society of Actuaries for all its plans, including those in which Dominion Gas participates.
Assumed healthcare cost trend rates have a significant effect on the amounts reported for Dominion's retiree healthcare plans, including those in which Dominion Gas participates. A one percentage point change in assumed healthcare cost trend rates would have had the following effects for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) other postretirement benefit plans:
	Other Postretirement Benefits
	One percentage point increase			One percentage point decrease
(millions)
DOMINION
Effect on net periodic cost for 2015	$	26		$	(16	)
Effect on other postretirement benefit obligation at December 31, 2014	186			(152		)
DOMINION GAS
Effect on net periodic cost for 2015	$	5		$	(4	)
Effect on other postretirement benefit obligation at December 31, 2014	40			(30		)
Dominion Gas (Employees Not Represented by Collective Bargaining Units) and Virginia Power - Participation in Defined Benefit Plans
Virginia Power employees and Dominion Gas employees not represented by collective bargaining units are covered by the Dominion Pension Plan described above. As participating employers, Virginia Power and Dominion Gas are subject to Dominion's funding policy, which is to contribute annually an amount that is in accordance with ERISA. During 2014, Virginia Power and Dominion Gas made no contributions to the Dominion Pension Plan, and no contributions to this plan are currently expected in 2015. Virginia Power's net periodic pension cost related to this plan was $75 million, $96 million and $72 million in 2014, 2013 and 2012, respectively. Dominion Gas' net periodic pension credit related to this plan was $(37) million, $(27) million and $(25) million in 2014, 2013 and 2012, respectively. Net periodic pension (credit) cost is reflected in other operations and maintenance expense in their respective Consolidated Statements of Income. The funded status of various Dominion subsidiary groups and employee compensation are the basis for determining the share of total pension costs for participating Dominion subsidiaries. See Note 24 for Virginia Power and Dominion Gas amounts due to/from Dominion related to this plan.
Retiree healthcare and life insurance benefits, for Virginia Power employees and for Dominion Gas employees not represented by collective bargaining units, are covered by the Dominion Retiree Health and Welfare Plan described above. Virginia Power's net periodic benefit (credit) cost related to this plan was $(18) million, $5 million and $13 million in 2014, 2013 and 2012, respectively. Dominion Gas' net periodic benefit (credit) cost related to this plan was $(5) million, less than $1 million and $3 million for 2014, 2013 and 2012, respectively. Net periodic benefit (credit) cost is reflected in other operations and maintenance expenses in their respective Consolidated Statements of Income. Employee headcount is the basis for determining the share of total other postretirement benefit costs for participating Dominion subsidiaries. See Note 24 for Virginia Power and Dominion Gas amounts due to/from Dominion related to this plan.
Dominion holds investments in trusts to fund employee benefit payments for the pension and other postretirement benefit plans in which Virginia Power and Dominion Gas' employees participate. Any investment-related declines in these trusts will result in future increases in the net periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of cash that Virginia Power and Dominion Gas will provide to Dominion for their shares of employee benefit plan contributions.
Certain regulatory authorities have held that amounts recovered in rates for other postretirement benefits, in excess of benefits actually paid during the year, must be deposited in trust funds dedicated for the sole purpose of paying such benefits. Accordingly, Virginia Power and Dominion Gas fund other postretirement benefit costs through VEBAs. During 2014 and 2013, Virginia Power made no contributions to the VEBA and does not expect to contribute to the VEBA in 2015. Dominion Gas' contributions to VEBAs for employees not represented by collective bargaining units were $1 million and $2 million for 2014 and 2013, respectively.
Defined Contribution Plans
Dominion also sponsors defined contribution employee savings plans that cover substantially all employees. During 2014, 2013 and 2012, Dominion recognized $41 million, $40 million and $40 million, respectively, as employer matching contributions to these plans. Dominion Gas participates in these employee savings plans, both specific to Dominion Gas and that cover multiple Dominion subsidiaries. During 2014, 2013 and 2012, Dominion Gas recognized $7 million, $7 million and $6 million, respectively, as employer matching contributions to these plans. Virginia Power also participates in these employee savings plans. During 2014, 2013 and 2012, Virgina Power recognized $17 million, $16 million and $15 million, respectively, as employer matching contributions to these plans.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES
	As a result of issues generated in the ordinary course of business, the Companies 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, 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 the financial position, liquidity or results of operations of the Companies.
	Environmental Matters
	The Companies 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 the Companies' facilities are subject to the CAA's permitting and other requirements.
	In December 2011, the EPA issued MATS for coal and oil-fired electric utility steam generating units. The rule establishes strict emission limits for mercury, particulate matter as a surrogate for toxic metals and hydrogen chloride as a surrogate for acid gases. The rule includes a limited use provision for oil-fired units with annual capacity factors under 8% that provides an exemption from emission limits, and allows compliance with operational work practice standards. Compliance will be required by April 16, 2015, with certain limited exceptions. In June 2014, the VDEQ granted a one-year MATS compliance extension for two coal-fired units at Yorktown to defer planned retirements and allow for continued operation of the units to address reliability concerns while necessary electric transmission upgrades are being completed. During the fourth quarter of 2013, Virginia Power recorded charges totaling $26 million ($16 million after-tax) for certain exit activities associated with these coal units, including the cost of employee severance, vendor contract termination, and inventory not expected to be used or usable at other stations.
	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. 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 a successful motion for stay, in October 2014, the U.S. Court of Appeals for the D.C. Circuit ordered that the EPA's motion to lift the stay of CSAPR be granted. Further, the Court granted the EPA's request to shift the CSAPR compliance deadlines by three years, so that Phase 1 emissions budgets (which would have gone into effect in 2012 and 2013) will apply in 2015 and 2016, and Phase 2 emissions budgets will apply in 2017 and beyond. CSAPR will replace CAIR beginning in January 2015. The cost to comply is not expected to be material to the Consolidated Financial Statements. Future outcomes of any additional litigation and/or any 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. A number of the Companies' 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. In November 2014, the EPA issued a new proposal to revise the ozone standard and expects to finalize the rule in October 2015. The EPA is not expected to complete attainment designations for a new standard until 2017 and states will have until 2020 to develop plans to address the new standard. Until the states have developed implementation plans, the Companies are unable to predict whether or to what extent the new rules will ultimately require additional controls. However, if significant expenditures are required to implement additional controls, it could adversely affect the Companies' results of operations and cash flows.
	In August 2010, the EPA issued revised National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. The rule was amended in March 2011 and January 2013. The rule establishes emission standards for control of hazardous air pollutants for engines at smaller facilities, known as area sources. As a result of these regulations, Dominion Gas installed emissions controls on several compressor engines. Dominion Gas has spent approximately $2 million to date and is evaluating further expenditures. Dominion Gas is unable to estimate the additional potential impacts on results of operations, financial condition and/or cash flows related to this matter.
	In August 2012, the EPA issued the first NSPS impacting the natural gas production and gathering sectors and made revisions to the NSPS for natural gas processing and transmission facilities. These rules establish equipment performance specifications and emissions standards for control of volatile organic compound emissions for natural gas production wells, tanks, pneumatic controllers, and compressors in the upstream sector. Compliance with these rules is required for installations and wells constructed or reconstructed after August 23, 2011. The cost to comply with the NSPS will depend on the number of new wells and new equipment installations subject to the rule; therefore, Dominion Gas is unable to estimate the potential impacts on results of operations, financial condition and/or cash flows related to this matter.
	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. The Companies must comply with applicable aspects of the CWA programs at their operating facilities.
	In October 2014, the final regulations under Section 316(b) of the CWA that govern existing facilities and new units at existing facilities that employ a cooling water intake structure and that have flow levels exceeding a minimum threshold became effective. The rule establishes a national standard for impingement based on seven compliance options, but forgoes the creation of a single technology standard for entrainment. Instead, the EPA has delegated entrainment technology decisions to state regulators. State regulators are to make case-by-case entrainment technology determinations after an examination of five mandatory facility-specific factors, including a social cost-benefit test, and six optional facility-specific factors. The rule governs all electric generating stations with water withdrawals above two mgd, with a heightened entrainment analysis for those facilities over 125 mgd. Dominion and Virginia Power have 14 and 11 facilities, respectively, that may be subject to the final regulations. Dominion anticipates that it will have to install impingement control technologies at many of these stations that have once-through cooling systems. Dominion and Virginia Power are currently evaluating the need or potential for entrainment controls under the final rule as these decisions will be made on a case-by-case basis after a thorough review of detailed biological, technology, cost and benefit studies. While the impacts of this rule could be material to Dominion's and Virginia Power's results of operations, financial condition and/or cash flows, the existing regulatory framework in Virginia provides rate recovery mechanisms that could substantially mitigate any such impacts for Virginia Power.
	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, Virginia Power, or Dominion Gas 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, Virginia Power, or Dominion Gas 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 and 12 of which pertain to Dominion Gas. 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 the Companies 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. Virginia Power is currently evaluating the nature and extent of the contamination from this site as well as potential remedial options. Preliminary costs for options under evaluation for the site range from $1 million to $22 million. Due to the uncertainty surrounding the other sites, the Companies are unable to make an estimate of the potential financial statement impacts.
	In December 2014, the EPA Administrator signed the final rule regulating the management of CCRs stored in impoundments (ash ponds) and landfills and designating those CCRs as nonhazardous wastes under Subtitle D of the RCRA. The final rule regulates CCR landfills, ash ponds that still receive and manage CCRs (existing ash ponds), and ash ponds that do not receive, but still store CCRs (inactive ash ponds). Virginia Power currently operates inactive ash ponds, existing ash ponds, and CCR landfills subject to the final rule at eight different facilities.  Virginia Power is also evaluating other features at its facilities for potential applicability under the final CCR rule.  It is likely that the final rule will cause Virginia Power to retrofit or close all of its inactive and existing ash ponds over a certain period of time. After closure of these structures, Virginia Power will continue to perform required monitoring, corrective action, and post-closure care activities as necessary to comply with the final rule. While Virginia Power is still evaluating the cost of compliance, it is expected that it may have a material impact to its financial position, results of operations or cash flows.
	CLIMATE CHANGE LEGISLATION AND REGULATION
	In October 2013, the U.S. Supreme Court granted petitions filed by several industry groups, states, and the U.S. Chamber of Commerce seeking review of the D.C. Circuit Court's June 2012 decision upholding the EPA’s regulation of GHG emissions from stationary sources under the CAA's permitting programs. In June 2014, the U.S. Supreme Court ruled that the EPA lacked the authority under the CAA to require PSD or Title V permits for stationary sources based solely on GHG emissions. However, the Court upheld the EPA’s ability to require BACT for GHG for sources that are otherwise subject to PSD or Title V permitting for conventional pollutants. On July 24, 2014, the EPA issued a memorandum specifying that it will no longer apply or enforce federal regulations or EPA-approved PSD state implementation plan provisions that require new and modified stationary sources to obtain a PSD permit when GHGs are the only pollutant that would be emitted at levels that exceed the permitting thresholds. In addition, the EPA stated that it will continue to use the existing thresholds to apply to sources that are otherwise subject to PSD for conventional pollutants until it completes a new rulemaking either justifying and upholding those thresholds or setting new ones. Some states have issued interim guidance that follows the EPA guidance. Due to uncertainty regarding what additional actions states may take to amend their existing regulations and what action the EPA ultimately takes to address the Court ruling under a new rulemaking, the Companies cannot predict the impact to their financial statements at this time.
	In July 2011, the EPA signed a final rule deferring the need for PSD and Title V permitting for CO2 emissions for biomass projects. This rule temporarily deferred for a period of up to three years the consideration of CO2 emissions from biomass projects when determining whether a stationary source meets the PSD and Title V applicability thresholds, including those for the application of BACT.  The deferral policy expired in July 2014. In July 2013, the U.S. Court of Appeals for the D.C. Circuit vacated this rule; however, a mandate making this decision effective has not been issued. Virginia Power converted three coal-fired generating stations, Altavista, Hopewell and Southampton, to biomass during the CO2 deferral period. It is unclear how the court's decision or the EPA's final policy regarding the treatment of specific feedstock will affect biomass sources that were permitted during the deferral period; however, the expenditures to comply with any new requirements could be material to Dominion's and Virginia Power's financial statements.
	Other Legal Matters
	The Companies are defendants in a number of lawsuits and claims involving unrelated incidents of property damage and personal injury. Due to the uncertainty surrounding these matters, the Companies are unable to make an estimate of the potential financial statement impacts; however, they could have a material impact on results of operations, financial condition and/or cash flows.
	Appalachian Gateway
	Following the completion of the Appalachian Gateway Project in 2012, DTI received multiple change order requests and other claims for additional payments from a pipeline contractor for the project. In July 2013, DTI filed a complaint in U.S. District Court, Eastern District of Virginia for breach of contract, accounting and declaratory relief. The contractor filed a motion to dismiss, or in the alternative, a motion to transfer venue to Pennsylvania and/or West Virginia, where the pipelines were constructed. DTI filed an opposition to the contractor’s motion in August 2013. In November 2013, the court granted the contractor’s motion on the basis that DTI must first comply with the dispute resolution process. Pursuant to the ruling, DTI intends to mediate the matter. This case is pending. DTI has accrued a liability of approximately $6 million for this matter. Dominion Gas cannot currently estimate additional financial statement impacts, but there could be a material impact to its financial condition and/or cash flows.
	Ash Pond Closure Costs
	In September 2014, Virginia Power received a notice from the SELC on behalf of the Potomac Riverkeeper and Sierra Club alleging CWA violations at the Possum Point Power Station. The notice alleges unpermitted discharges to surface water and groundwater from Possum Point's historical and active ash storage facilities. A similar notice from the SELC on behalf of Sierra Club was subsequently received related to Chesapeake. In December 2014, Virginia Power offered to close all of its coal ash ponds and landfills at Possum Point, Chesapeake and Bremo to the SELC as settlement of the potential litigation. In January 2015, the SELC declined the offer as presented, however the issue is open to potential further negotiations. As a result of the settlement offer, Virginia Power recognized a charge of $121 million in other operations and maintenance expense in its Consolidated Statements of Income.
	Cove Point
	Dominion is constructing the Liquefaction Project at the Cove Point facility, which would enable the facility to liquefy domestically-produced natural gas and export it as LNG. In April 2013, Cove Point filed with FERC for permission to build liquefaction and other facilities related to the export of natural gas. In September 2014, FERC issued an order granting authorization for Cove Point to construct, modify and operate the Liquefaction Project. In October 2014, several parties filed a motion with FERC to stay the order and requested rehearing. The order remains in effect pending consideration of the motion by FERC.
	In April 2013, Cove Point filed an application with the Maryland Commission requesting authorization to construct a generating station in connection with the Liquefaction Project. In May 2014, the Maryland Commission granted the CPCN authorizing the construction of such generating station. The CPCN obligates Cove Point to make payments totaling approximately $48 million. These payments consist of $40 million to the Strategic Energy Investments Fund over a five-year period beginning in 2015 and $8 million to Maryland low income energy assistance programs over a twenty-year period expected to begin in 2018. In December 2014, upon receipt of applicable approvals to commence construction of the generating station, Dominion recorded the present value of the obligation as an increase to property, plant and equipment and a corresponding liability.
	In June 2014, a party filed a notice of petition for judicial review of the CPCN with the Circuit Court for Baltimore City in Maryland. In September 2014, the party filed with the Maryland Commission a motion to stay the CPCN pending judicial review of the CPCN.  In December 2014, the Circuit Court issued an order affirming the Maryland Commission’s grant of the CPCN and dismissing the appeal, and the motion for stay was denied by the Maryland Commission.  In January 2015, the same party filed a Notice of Appeal of the Baltimore Circuit Court’s Order affirming the Maryland Commission’s grant of the CPCN with the Court of Special Appeals for the Circuit Court of Baltimore City. This appeal is pending.
	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 Decommissioning - Minimum Financial Assurance
	The NRC requires nuclear power plant owners to annually update minimum financial assurance amounts for the future decommissioning of their nuclear facilities. Decommissioning involves the decontamination and removal of radioactive contaminants from a nuclear power station once operations have ceased, in accordance with standards established by the NRC. The 2014 calculation for the NRC minimum financial assurance amount, aggregated for Dominion's and Virginia Power's nuclear units, excluding joint owners' assurance amounts and Millstone Unit 1 and Kewaunee, as those units are in a decommissioning state, was $2.9 billion and $1.8 billion, respectively, and has been satisfied by a combination of the funds being collected and deposited in the nuclear decommissioning trusts and the real annual rate of return growth of the funds allowed by the NRC. The 2014 NRC minimum financial assurance amounts above were calculated using preliminary December 31, 2014 U.S. Bureau of Labor Statistics indices. Dominion believes that the amounts currently available in its decommissioning trusts and their expected earnings will be sufficient to cover expected decommissioning costs for the Millstone and Kewaunee units. Virginia Power also believes that the decommissioning funds and their expected earnings for the Surry and North Anna units will be sufficient to cover decommissioning costs, particularly when combined with future ratepayer collections and contributions to these decommissioning trusts, if such future collections and contributions are required. This reflects a positive long-term outlook for trust fund investment returns as the decommissioning of the units will not be complete for decades. Dominion and Virginia Power will continue to monitor these trusts to ensure they meet the NRC minimum financial assurance requirement, which may include, if needed, the use of parent company guarantees, surety bonding or other financial instruments recognized by the NRC. See Note 6 to the Consolidated Financial Statements for additional information on Kewaunee, and Note 9 for additional information on nuclear decommissioning trust investments.
	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.
	The current levels of nuclear property insurance coverage for Dominion's and Virginia Power's nuclear units is as follows:
		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 $200 million.
	Dominion's and Virginia Power's 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 $72 million and $42 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 $20 million and $9 million, respectively.
	ODEC, a part owner of North Anna, and Massachusetts Municipal and Green Mountain, 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.
	Spent Nuclear Fuel
	Dominion and Virginia Power entered into contracts with the DOE for the disposal of spent nuclear fuel under provisions of the Nuclear Waste Policy Act of 1982. The DOE failed to begin accepting the spent fuel on January 31, 1998, the date provided by the Nuclear Waste Policy Act and by Dominion's and Virginia Power's contracts with the DOE. Dominion and Virginia Power have previously received damages award payments and settlement payments related to these contracts.
	In 2012, Dominion and Virginia Power resolved additional claims for damages incurred at Millstone, Kewaunee, Surry and North Anna with the Authorized Representative of the Attorney General. Dominion and Virginia Power entered into settlement agreements that resolved claims for damages incurred through December 31, 2010, and also provided for periodic payments after that date for damages incurred through December 31, 2013.
	By mutual agreement of the parties, the settlement agreements are extendable to provide for resolution of damages incurred after 2013. The settlement agreements for the Surry, North Anna and Millstone plants have been extended to provide for periodic payments for damages incurred through December 31, 2016. Possible extension of the Kewaunee settlement agreement is being evaluated.
	In 2014, Virginia Power and Dominion received payments of $27 million for the resolution of claims incurred at North Anna and Surry for the period January 1, 2011 through December 31, 2012 and $17 million for the resolution of claims incurred at Millstone for the period of July 1, 2012 through June 30, 2013. In 2014, Dominion also received payments totaling $7 million for the resolution of claims incurred at Kewaunee for periods from January 1, 2011 through December 31, 2013. In 2013, Dominion received payment of $5 million for resolution of claims incurred at Millstone for the period January 1, 2011 through June 30, 2012.
	Dominion and Virginia Power continue to recognize receivables for certain spent nuclear fuel-related costs that they believe are probable of recovery from the DOE. Dominion's receivables for spent nuclear fuel-related costs totaled $69 million and $79 million at December 31, 2014 and 2013, respectively. Virginia Power's receivables for spent nuclear fuel-related costs totaled $41 million and $50 million at December 31, 2014 and 2013, respectively.
Pursuant to a November 2013 decision of the U.S Court of Appeals for the D.C. Circuit, in January 2014 the Secretary of the DOE sent a recommendation to the U.S. Congress to adjust to zero the current fee of $1 per MWh for electricity paid by civilian nuclear power generators for disposal of spent nuclear fuel. The processes specified in the Nuclear Waste Policy Act for adjustment of the fee have been completed, and as of May 2014, Dominion and Virginia Power are no longer required to pay the waste fee. In 2014, Dominion and Virginia Power recognized fees of $16 million and $10 million, respectively.
Dominion and Virginia Power will continue to manage their spent fuel until it is accepted by the DOE.
Long-Term Purchase Agreements
At December 31, 2014, Virginia Power had the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that third parties have used to secure financing for the facilities that will provide the contracted goods or services:
	2015		2016		2017		2018		2019		Thereafter		Total
(millions)
Purchased electric capacity(1)	$	313	$	250	$	158	$	104	$	65	$	99	$	989
-1	Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities and independent power producers, the last of which ends in 2021. Capacity payments under the contracts are generally based on fixed dollar amounts per month, subject to escalation using broad-based economic indices. At December 31, 2014, the present value of Virginia Power's total commitment for capacity payments is $833 million. Capacity payments totaled $330 million, $345 million, and $337 million, and energy payments totaled $304 million, $236 million, and $214 million for the years ended 2014, 2013 and 2012, respectively.
Lease Commitments
The Companies' lease various facilities, vehicles and equipment primarily under operating leases. Payments under certain leases are escalated based on an index such as the consumer price index. Future minimum lease payments under noncancelable operating and capital leases that have initial or remaining lease terms in excess of one year as of December 31, 2014 are as follows:
	2015		2016		2017		2018		2019		Thereafter		Total
(millions)
Dominion	$	63	$	57	$	49	$	43	$	36	$	79	$	327
Virginia Power	$	30	$	26	$	21	$	18	$	12	$	26	$	133
Dominion Gas	$	28	$	25	$	23	$	21	$	19	$	25	$	141
Rental expense for Dominion totaled $92 million, $101 million, and $112 million for 2014, 2013 and 2012, respectively. Rental expense for Virginia Power totaled $43 million, $42 million, and $48 million for 2014, 2013, and 2012, respectively. Rental expense for Dominion Gas totaled $35 million in 2014 and $15 million in each 2013 and 2012. The majority of rental expense is reflected in other operations and maintenance expense in the Consolidated Statements of Income.
Guarantees, Surety Bonds and Letters of Credit
DOMINION
At December 31, 2014, Dominion had issued $74 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of December 31, 2014, Dominion's exposure under these guarantees was $49 million, primarily related to certain reserve requirements associated with non-recourse financing.
Dominion also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. To the extent that a liability subject to a guarantee has been incurred by one of Dominion's consolidated subsidiaries, that liability is included in 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 December 31, 2014, Dominion had issued the following subsidiary guarantees:
	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	27	$	27
Commodity transactions(3)	3,151		919
Nuclear obligations(4)	215		76
Cove Point(5)	1,910		—
Solar(6)	531		396
Other(7)	532		35
Total	$	6,366	$	1,453
-1	Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2014 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 commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power, Dominion Gas 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 (in the event of a prolonged outage) and Kewaunee, respectively, 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, in support of terminal services, transportation and construction. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million.
-6	Includes guarantees to facilitate the development of solar projects including guarantees to support the issuance of full notice to proceed under EPC agreements. Includes certain guarantees that do not have stated limits. Also includes guarantees entered into by DEI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects.
-7	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. As of December 31, 2014, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $72 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million. The value provided includes certain guarantees that do not have stated limits.
Additionally, at December 31, 2014, Dominion had purchased $133 million of surety bonds, including $64 million at Virginia Power and $30 million at Dominion Gas, and authorized the issuance of letters of credit by financial institutions of $48 million 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.
As of December 31, 2014, Virginia Power had issued $14 million of guarantees primarily to support tax-exempt debt issued through conduits. The related debt matures in 2031. In the event of default by a conduit, Virginia Power would be obligated to repay such amounts, which are limited to the principal and interest then outstanding.
Indemnifications
As part of commercial contract negotiations in the normal course of business, the Companies may sometimes agree to make payments to compensate or indemnify other parties for possible future unfavorable financial consequences resulting from specified events. The specified events may involve an adverse judgment in a lawsuit or the imposition of additional taxes due to a change in tax law or interpretation of the tax law. The Companies are unable to develop an estimate of the maximum potential amount of any other future payments under these contracts because events that would obligate them have not yet occurred or, if any such event has occurred, they have not been notified of its occurrence. However, at December 31, 2014, the Companies believe any other future payments, if any, that could ultimately become payable under these contract provisions, would not have a material impact on their results of operations, cash flows or financial position.

Credit_Risk

Credit Risk	12 Months Ended
	Dec. 31, 2014
Risks and Uncertainties [Abstract]
Credit Risk	CREDIT RISK
	Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition, collateral requirements and the use of standardized agreements that facilitate the netting of cash flows associated with a single counterparty. In addition, counterparties may make available collateral, including letters of credit or cash held as margin deposits, as a result of exceeding agreed-upon credit limits, or may be required to prepay the transaction.
	The Companies maintain a provision for credit losses based on factors surrounding the credit risk of their customers, historical trends and other information. Management believes, based on credit policies and the December 31, 2014 provision for credit losses, that it is unlikely that a material adverse effect on financial position, results of operations or cash flows would occur as a result of counterparty nonperformance.
	General
	Dominion
	As a diversified energy company, Dominion transacts primarily with major companies in the energy industry and with commercial and residential energy consumers. These transactions principally occur in the Northeast, mid-Atlantic and Midwest regions of the U.S. Dominion does not believe that this geographic concentration contributes significantly to its overall exposure to credit risk. In addition, as a result of its large and diverse customer base, Dominion is not exposed to a significant concentration of credit risk for receivables arising from electric and gas utility operations.
	Dominion's exposure to credit risk is concentrated primarily within its energy marketing and price risk management activities, as Dominion transacts with a smaller, less diverse group of counterparties and transactions may involve large notional volumes and potentially volatile commodity prices. Energy marketing and price risk management activities include marketing of merchant generation output, structured transactions and the use of financial contracts for enterprise-wide hedging purposes. Gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of any collateral. At December 31, 2014, Dominion's credit exposure totaled $228 million. Of this amount, investment grade counterparties, including those internally rated, represented 86%, and no single counterparty, whether investment grade or non-investment grade, exceeded $23 million of exposure.
	Virginia Power
	Virginia Power sells electricity and provides distribution and transmission services to customers in Virginia and northeastern North Carolina. Management believes that this geographic concentration risk is mitigated by the diversity of Virginia Power's customer base, which includes residential, commercial and industrial customers, as well as rural electric cooperatives and municipalities. Credit risk associated with trade accounts receivable from energy consumers is limited due to the large number of customers. Virginia Power's exposure to potential concentrations of credit risk results primarily from sales to wholesale customers. Virginia Power's gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of collateral. At December 31, 2014, Virginia Power's exposure to potential concentrations of credit risk was not considered material.
	Dominion Gas
	Dominion Gas transacts mainly with major companies in the energy industry and with residential and commercial energy consumers. These transactions principally occur in the Northeast, mid-Atlantic and Midwest regions of the U.S. Dominion Gas does not believe that this geographic concentration contributes to its overall exposure to credit risk. In addition, as a result of its large and diverse customer base, Dominion Gas is not exposed to a significant concentration of credit risk for receivables arising from gas utility operations.
	In 2014, DTI provided service to 260 customers with approximately 94% of its storage and transportation revenue being provided through firm services. The ten largest customers provided approximately 41% of the total storage and transportation revenue and the thirty largest provided approximately 74% of the total storage and transportation revenue of approximately $718 million. Approximately 99% of the transmission capacity under contract on DTI’s pipeline is subscribed with long-term contracts (three years or greater). The remaining 1% is contracted on a year-to-year basis. Less than 1% of firm transportation capacity is currently unsubscribed. All storage services are subscribed under long-term contracts.
	East Ohio distributes natural gas to residential, commercial and industrial customers in Ohio using rates established by the Ohio Commission. Approximately 98% of East Ohio revenues are derived from its regulated gas distribution services. While individual customers of East Ohio have had increased amounts of bad debt in recent years, management believes that this concentration and bad debt risk is mitigated by the regulatory framework established by the Ohio Commission. See Note 13 for further information about Ohio’s PIPP and UEX Riders that mitigate East Ohio’s overall credit risk.
	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 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 December 31, 2014 and 2013, Dominion would have been required to post an additional $20 million and $146 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 $1 million in collateral at December 31, 2014 and $76 million in collateral at December 31, 2013, 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 December 31, 2014 and 2013 was $49 million and $169 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power and Dominion Gas were not material as of December 31, 2014 and 2013. See Note 7 for further information about derivative instruments.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related-Party Transactions	RELATED-PARTY TRANSACTIONS
	Virginia Power and Dominion Gas engage in related party transactions primarily with other Dominion subsidiaries (affiliates). Virginia Power's and Dominion Gas' 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 and Dominion Gas are included in Dominion's consolidated federal income tax return. A discussion of significant related party transactions follows.
	Virginia Power
	Transactions with Affiliates
	Virginia Power transacts with affiliates for certain quantities of natural gas and other commodities in the ordinary course of business. Virginia Power also enters into certain commodity derivative contracts with affiliates. Virginia Power uses these contracts, which are principally comprised of commodity swaps, to manage commodity price risks associated with purchases of natural gas. See Notes 7 and 19 for more information. As of December 31, 2014 and 2013, Virginia Power's derivative assets and liabilities with affiliates were not material.
	Virginia Power participates in certain Dominion benefit plans as described in Note 21. At December 31, 2014 and 2013, Virginia Power's amounts due to Dominion associated with the Dominion Pension Plan and reflected in noncurrent pension and other postretirement benefit liabilities in the Consolidated Balance Sheets, were $219 million and $144 million, respectively. At December 31, 2014, Virginia Power's amounts due from Dominion associated with the Dominion Retiree Health and Welfare Plan and reflected in other deferred charges and other assets in the Consolidated Balance Sheets were $37 million and at December 31, 2013, amounts due to Dominion and reflected in noncurrent pension and other postretirement benefit liabilities were $3 million.
	DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Virginia Power. In addition, Virginia Power provides certain services to affiliates, including charges for facilities and equipment usage.
	Presented below are significant transactions with DRS and other affiliates:
	Year Ended December 31,	2014		2013		2012
	(millions)
	Commodity purchases from affiliates	$	543	$	417	$	368
	Services provided by affiliates(1)	432		415		399
	Services provided to affiliates	22		21		19
	(1) Includes capitalized expenditures.
	Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. There were $427 million and $97 million in short-term demand note borrowings from Dominion as of December 31, 2014 and 2013, respectively. Virginia Power had no outstanding borrowings, net of repayments under the Dominion money pool for its nonregulated subsidiaries as of December 31, 2014 and 2013. Interest charges related to Virginia Power's borrowings from Dominion were immaterial for the years ended December 31, 2014, 2013 and 2012.
	There were no issuances of Virginia Power's common stock to Dominion in 2014, 2013 or 2012.
	Dominion Gas
	Transactions with Affiliates
	Dominion Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Gas provides transportation and storage services to affiliates. Dominion Gas also enters into certain other contracts with affiliates, which are presented separately from contracts involving commodities or services. As of December 31, 2014 and 2013, all of Dominion Gas' commodity derivatives were with affiliates. See Notes 7 and 19 for more information. See Note 9 for information regarding sales of assets to an affiliate.
	Dominion Gas participates in certain Dominion benefit plans as described in Note 21. At December 31, 2014 and 2013, Dominion Gas' amounts due from Dominion associated with the Dominion Pension Plan and reflected in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets, were $614 million and $577 million, respectively. At December 31, 2014 and 2013, Dominion Gas' liabilities to Dominion associated with the Dominion Retiree Health and Welfare Plan and reflected in other deferred credits and other liabilities in the Consolidated Balance Sheets were $7 million and $14 million, respectively.
	Year Ended December 31,	2014		2013		2012
	(millions)
	Purchases of natural gas and transportation and storage services from affiliates	$	34	$	31	$	14
	Sales of natural gas and transportation and storage services to affiliates	84		109		64
	DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to affiliates, including technical services. The costs of these services follow:
	Year Ended December 31,	2014		2013		2012
	(millions)
	Services provided by affiliates(1)	$	106	$	116	$	107
	Services provided to affiliates	17		4		3
	(1) Includes capitalized expenditures.
	The following table presents affiliated and related party activity reflected in Dominion Gas' Consolidated Balance Sheets:
		December 31,
		2014		2013
	(millions)
	Customer receivables from related parties(1)	$	22	$	3
	Imbalances receivable from affiliates(2)	3		6
	Imbalances payable to affiliates(3)	—		1
	Affiliated notes receivable(4)	9		5
	-1	Includes $17 million due from Atlantic Coast Pipeline, an affiliated VIE.
	-2	Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.
	(3) Amounts are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.
	(4) Amounts are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.
	Dominion Gas' borrowings under the IRCA with Dominion totaled $384 million and $1.3 billion as of December 31, 2014 and 2013, respectively. Interest charges related to Dominion Gas' total borrowings from Dominion were $4 million, $35 million and $61 million for the years ended December 31, 2014, 2013 and 2012, respectively.

Operating_Segments

Operating Segments	12 Months Ended
	Dec. 31, 2014
Segment Reporting Information, Revenue for Reportable Segment [Abstract]
Operating Segments	OPERATING SEGMENTS
	The Companies 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	Description of Operations	Dominion	Virginia	Dominion Gas
	Segment			Power
	DVP	Regulated electric distribution	X	X
		Regulated electric transmission	X	X
	Dominion Generation	Regulated electric fleet	X	X
		Merchant electric fleet	X
		Nonregulated retail energy marketing	X
	Dominion Energy	Gas transmission and storage(1)	X		X
		Gas distribution and storage	X		X
		Gas gathering and processing	X		X
		LNG import and storage	X
	(1) Includes remaining producer services activities.
	In addition to the operating segments above, the Companies also report a Corporate and Other segment.
	Dominion
	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 discontinued or sold. 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 January 2014, Dominion announced it would exit the electric retail energy marketing business. Dominion completed the sale in March 2014. As a result, the earnings impact from the electric retail energy marketing business has been included in the Corporate and Other Segment of Dominion for 2014 first quarter results of operations.
	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, which was completed in the first quarter of 2014, resulted 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 for 2014.
	In 2014, Dominion reported after-tax net expense of $970 million in the Corporate and Other segment, with $544 million of these net expenses attributable to specific items related to its operating segments.
	The net expenses for specific items in 2014 primarily related to the impact of the following items:
	•	$374 million ($248 million after-tax) in charges associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities, attributable to Dominion Generation;
	•	A $319 million ($193 million after-tax) net loss related to the producer services business discussed above, attributable to Dominion Energy; and
	•	A $121 million ($74 million after-tax) charge related to a settlement offer to incur future ash pond closure costs at certain utility generation facilities, attributable to Dominion Generation.
	In 2013, Dominion reported after-tax net expense of $452 million in the Corporate and Other segment, with $184 million of these net expenses attributable to specific items related to its operating segments.
	The net expenses 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; and
	•	A $182 million ($109 million after-tax) net loss, including a $55 million ($33 million after-tax) impairment charge related to certain natural gas infrastructure assets and a $127 million ($76 million after-tax) loss related to the producer services business discussed above, attributable to Dominion Energy; partially offset by
	•	An $81 million ($49 million after-tax) net gain on investments held in nuclear decommissioning trust funds, attributable to Dominion Generation.
	In 2012, Dominion reported after-tax net expense of $1.7 billion in the Corporate and Other segment, with $1.5 billion of these net expenses attributable to specific items related to its operating segments.
	The net expenses for specific items in 2012 primarily related to the impact of the following items:
	•	A $1.7 billion ($1.1 billion after-tax) net loss from discontinued operations, including impairment charges, of Brayton Point and Kincaid, which were sold in 2013, attributable to Dominion Generation;
	•	A $467 million ($303 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;
	•	An $87 million ($53 million after-tax) charge reflecting restoration costs associated with damage caused by severe 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 following table presents segment information pertaining to Dominion's operations:
	Year Ended December 31,	DVP			Dominion			Dominion			Corporate and			Adjustments &			Consolidated
					Generation			Energy			Other			Eliminations			Total
	(millions)
	2014
	Total revenue from external customers	$	1,918		$	7,665		$	1,718		$	(12	)	$	1,147		$	12,436
	Intersegment revenue	18			70			1,174			572			(1,834		)	—
	Total operating revenue	1,936			7,735			2,892			560			(687		)	12,436
	Depreciation, depletion and amortization	462			516			241			73			—			1,292
	Equity in earnings of equity method investees	—			(18		)	54			10			—			46
	Interest income	—			67			14			20			(33		)	68
	Interest and related charges	205			240			11			770			(33		)	1,193
	Income taxes	317			392			436			(693		)	—			452
	Net income (loss) attributable to Dominion	502			1,101			677			(970		)	—			1,310
	Investment in equity method investees	—			262			796			23			—			1,081
	Capital expenditures	1,652			2,466			1,329			104			—			5,551
	Total assets (billions)	13			24.2			12.7			8.7			(4.3		)	54.3
	2013
	Total revenue from external customers	$	1,825		$	8,445		$	1,783		$	3		$	1,064		$	13,120
	Intersegment revenue	9			68			1,063			609			(1,749		)	—
	Total operating revenue	1,834			8,513			2,846			612			(685		)	13,120
	Depreciation, depletion and amortization	427			518			228			35			—			1,208
	Equity in earnings of equity method investees	—			(14		)	21			7			—			14
	Interest income	—			66			12			42			(66		)	54
	Interest and related charges	175			220			26			522			(66		)	877
	Income taxes	287			483			409			(287		)	—			892
	Loss from discontinued operations, net of tax	—			—			—			(92		)	—			(92		)
	Net income (loss) attributable to Dominion	475			1,031			643			(452		)	—			1,697
	Investment in equity method investees	—			280			615			21			—			916
Capital expenditures	1,361			1,605			1,043			95			—			4,104
Total assets (billions)	11.9			22			12.1			8.5			(4.4		)	50.1
2012
Total revenue from external customers	$	1,846		$	8,170		$	1,813		$	155		$	851		$	12,835
Intersegment revenue	9			104			930			608			(1,651		)	—
Total operating revenue	1,855			8,274			2,743			763			(800		)	12,835
Depreciation, depletion and amortization	392			483			216			36			—			1,127
Equity in earnings of equity method investees	—			3			23			(1		)	—			25
Interest income	1			65			30			71			(106		)	61
Interest and related charges	187			177			47			511			(106		)	816
Income taxes	278			576			352			(395		)	—			811
Loss from discontinued operations, net of tax	—			—			—			(1,125		)	—			(1,125		)
Net income (loss) attributable to Dominion	439			1,021			551			(1,709		)	—			302
Capital expenditures	1,158			1,615			1,350			22			—			4,145
Intersegment sales and transfers for Dominion are based on contractual arrangements and may result in intersegment profit or loss that is eliminated in consolidation.
Virginia Power
The majority of Virginia Power's revenue is provided through tariff rates. Generally, such revenue is allocated for management reporting based on an unbundled rate methodology among Virginia Power's DVP and Dominion Generation segments.
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 2014, Virginia Power reported after-tax net expenses of $342 million for specific items attributable to its operating segments in the Corporate and Other segment.
The net expenses for specific items in 2014 primarily related to the impact of the following:
•	$374 million ($248 million after-tax) in charges associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities, attributable to Dominion Generation; and
•	A $121 million ($74 million after-tax) charge related to a settlement offer to incur future ash pond closure costs at certain utility generation facilities, attributable to Dominion Generation.
In 2013, Virginia Power reported after-tax net expenses of $47 million for specific items attributable to its operating segments in the Corporate and Other segment.
The net expenses for specific items in 2013 primarily related to the impact of the following:
•	A $40 million ($28 million after-tax) charge in connection with the 2013 Biennial Review Order, attributable to Dominion Generation.
In 2012, Virginia Power reported after-tax net expenses of $51 million for specific items attributable to its operating segments in the Corporate and Other segment.
The net expenses for specific items in 2012 primarily related to the impact of the following:
•	An $87 million ($53 million after-tax) charge reflecting restoration costs associated with damage caused by severe storms, attributable to DVP.
The following table presents segment information pertaining to Virginia Power's operations:
Year Ended December 31,	DVP			Dominion			Corporate and			Adjustments &			Consolidated
				Generation			Other			Eliminations			Total
(millions)
2014
Operating revenue	$	1,928		$	5,651		$	—		$	—		$	7,579
Depreciation and amortization	462			416			37			—			915
Interest income	—			8			—			—			8
Interest and related charges	205			203			3			—			411
Income taxes	317			416			(185		)	—			548
Net income (loss)	509			691			(342		)	—			858
Capital expenditures	1,651			1,456			—			—			3,107
Total assets (billions)	13.2			16.4			—			(0.1		)	29.5
2013
Operating revenue	$	1,826		$	5,475		$	(6	)	$	—		$	7,295
Depreciation and amortization	427			425			1			—			853
Interest income	—			6			—			—			6
Interest and related charges	175			192			2			—			369
Income taxes	286			399			(26		)	—			659
Net income (loss)	483			702			(47		)	—			1,138
Capital expenditures	1,360			1,173			—			—			2,533
Total assets (billions)	12			15.1			—			(0.1		)	27
2012
Operating revenue	$	1,847		$	5,379		$	—		$	—		$	7,226
Depreciation and amortization	392			390			—			—			782
Interest income	1			7			—			—			8
Interest and related charges	186			199			—			—			385
Income taxes	277			403			(27		)	—			653
Net income (loss)	448			653			(51		)	—			1,050
Capital expenditures	1,142			1,146			—			—			2,288
Dominion Gas
The Corporate and Other Segment of Dominion Gas primarily includes specific items attributable to Dominion Gas' operating segment that are not included in profit measures evaluated by executive management in assessing the segment's performance and the effect of certain items recorded at Dominion Gas as a result of Dominion's basis in the net assets contributed.
In 2014, Dominion Gas reported after-tax net expenses of $9 million in its Corporate and Other segment, with none of these net expenses attributable to specific items related to its operating segment.
In 2013, Dominion Gas reported after-tax net expenses of $49 million in the Corporate and Other segment, with $41 million of these net expenses attributable to specific items related to its operating segment.
The net expenses for specific items in 2013 primarily related to the impact of the following:
•	$55 million ($33 million after-tax) of impairment charges related to certain natural gas infrastructure assets; and
•	A $14 million ($8 million after-tax) charge primarily reflecting severance pay and other benefits related to workforce reductions.
In 2012, Dominion Gas reported after-tax net expenses of $10 million in its Corporate and Other segment, with none of these net expenses attributable to specific items related to its operating segment.
The following table presents segment information pertaining to Dominion Gas' operations:
Year Ended December 31,	Dominion Energy			Corporate and			Consolidated
				Other			Total
(millions)
2014
Operating revenue	$	1,898		$	—		$	1,898
Depreciation and amortization	197			—			197
Equity in earnings of equity method investees	21			—			21
Interest income	1			—			1
Interest and related charges	27			—			27
Income taxes	340			(6		)	334
Net income (loss)	521			(9		)	512
Investment in equity method investees	107			—			107
Capital expenditures	719			—			719
Total assets (billions)	9.2			0.6			9.8
2013
Operating revenue	$	1,937		$	—		$	1,937
Depreciation and amortization	188			—			188
Equity in earnings of equity method investees	22			—			22
Interest income	2			—			2
Interest and related charges	28			—			28
Income taxes	333			(32		)	301
Net income (loss)	510			(49		)	461
Investment in equity method investees	105			—			105
Capital expenditures	650			—			650
Total assets (billions)	8.5			0.6			9.1
2012
Operating revenue	$	1,677		$	—		$	1,677
Depreciation and amortization	176			—			176
Equity in earnings of equity method investees	23			—			23
Interest income	2			—			2
Interest and related charges	40			—			40
Income taxes	293			(5		)	288
Net income (loss)	469			(10		)	459
Capital expenditures	928			—			928

Quarterly_Financial_and_Common

Quarterly Financial and Common Stock Data (Unaudited)	12 Months Ended
	Dec. 31, 2014
Selected Quarterly Financial Information [Abstract]
Quarterly Financial and Common Stock Data (Unaudited)	QUARTERLY FINANCIAL AND COMMON STOCK DATA (UNAUDITED)
	A summary of the Companies' quarterly results of operations for the years ended December 31, 2014 and 2013 follows. Amounts reflect all adjustments necessary in the opinion of management for a fair statement of the results for the interim periods. Results for interim periods may fluctuate as a result of weather conditions, changes in rates and other factors.
	Dominion
		First		Second			Third			Fourth		Year
		Quarter		Quarter			Quarter			Quarter
	(millions, except per share amounts)
	2014
	Operating revenue	$	3,630	$	2,813		$	3,050		$	2,943	$	12,436
	Income from operations	768		394			921			638		2,721
	Net income including noncontrolling interests	385		161			531			249		1,326
	Income from continuing operations(1)	379		159			529			243		1,310
	Net income attributable to Dominion	379		159			529			243		1,310
	Basic EPS:
	Income from continuing operations(1)	0.65		0.27			0.91			0.42		2.25
	Net income attributable to Dominion	0.65		0.27			0.91			0.42		2.25
	Diluted EPS:
	Income from continuing operations(1)	0.65		0.27			0.9			0.42		2.24
	Net income attributable to Dominion	0.65		0.27			0.9			0.42		2.24
	Dividends declared per share	0.6		0.6			0.6			0.6		2.4
	Common stock prices (intraday high-low)	$72.22  -		$73.75  -			$71.62 - 64.71			$80.89  -		$80.89  -
		63.14		67.06						65.53		63.14
	2013
	Operating revenue	$	3,523	$	2,980		$	3,432		$	3,185	$	13,120
	Income from operations	930		548			1,034			804		3,316
	Net income including noncontrolling interests	502		208			575			435		1,720
	Income from continuing operations(1)	494		272			592			431		1,789
	Income (loss) from discontinued operations(1)	1		(70		)	(23		)	—		(92		)
	Net income attributable to Dominion	495		202			569			431		1,697
	Basic EPS:
	Income from continuing operations(1)	0.86		0.47			1.02			0.74		3.09
	Income (loss) from discontinued operations(1)	—		(0.12		)	(0.04		)	—		(0.16		)
	Net income attributable to Dominion	0.86		0.35			0.98			0.74		2.93
	Diluted EPS:
	Income from continuing operations(1)	0.86		0.47			1.02			0.74		3.09
	Income (loss) from discontinued operations(1)	—		(0.12		)	(0.04		)	—		(0.16		)
	Net income attributable to Dominion	0.86		0.35			0.98			0.74		2.93
	Dividends declared per share	0.5625		0.5625			0.5625			0.5625		2.25
	Common stock prices (intraday high-low)	$58.25  -		$61.85  -			$64.04 - 55.51			$67.97  -		$67.97  -
		51.92		53.79						61.36		51.92
	-1	Amounts attributable to Dominion's common shareholders.
	Dominion's 2014 results include the impact of the following significant items:
	•	Fourth quarter results include $172 million in after-tax charges associated with the Liability Management Exercise in 2014 and $74 million in after-tax costs related to Virginia Power's settlement offer to incur future ash pond closure costs at certain utility generation facilities.
	•	Second quarter results include $191 million in after-tax charges associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities.
	•	First quarter results include a $193 million after-tax reduction in revenues associated with the repositioning of Dominion's producer services business which was completed in the first quarter of 2014.
	Dominion's 2013 results include the impact of the following significant items:
	•	Second quarter results include a $70 million after-tax net loss from discontinued operations of Brayton Point and Kincaid; and a $57 million after-tax net loss, including a $33 million after-tax impairment charge related to certain natural gas infrastructure assets and a $24 million after-tax loss related to the producer services business.
	Virginia Power
	Virginia Power's quarterly results of operations were as follows:
		First		Second			Third			Fourth		Year
		Quarter		Quarter			Quarter			Quarter
	(millions)
	2014
	Operating revenue	$	1,983	$	1,729		$	2,053		$	1,814	$	7,579
	Income from operations	613		205			594			312		1,724
	Net income	324		69			314			151		858
	Balance available for common stock	318		67			312			148		845
	2013
	Operating revenue	$	1,781	$	1,710		$	2,059		$	1,745	$	7,295
	Income from operations	530		463			679			408		2,080
	Net income	287		265			387			199		1,138
	Balance available for common stock	283		261			383			194		1,121
	Virginia Power's 2014 results include the impact of the following significant items:
	•	Fourth quarter results include $74 million in after-tax costs related to Virginia Power's settlement offer to incur future ash pond closure costs at certain utility generation facilities.
	•	Second quarter results include a $191 million after-tax charge associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities.
Virginia Power's 2013 results include the impact of the following significant item:
•	Fourth quarter results include a $28 million after-tax charge resulting from impacts of the 2013 Biennial Review Order.
Dominion Gas
Dominion Gas' quarterly results of operations were as follows:
	First		Second			Third			Fourth		Year
	Quarter		Quarter			Quarter			Quarter
(millions)
2014
Operating revenue	$	569	$	428		$	391		$	510	$	1,898
Income from operations	265		154			177			255		851
Net income	164		93			107			148		512
2013
Operating revenue	$	586	$	430		$	388		$	533	$	1,937
Income from operations	224		88			217			233		762
Net income	138		53			130			140		461
Dominion Gas' 2014 results include the impact of the following significant item:
•	Fourth quarter results include a $36 million after-tax gain from agreements to convey Marcellus Shale development rights underneath several natural gas storage fields.
Dominion Gas' 2013 results include the impact of the following significant item:
•	Second quarter results include a $33 million after-tax charge resulting from the impairment of certain natural gas infrastructure assets.

Significant_Accounting_Policie1

Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Operating Revenue	Operating Revenue
	Operating revenue is recorded on the basis of services rendered, commodities delivered or contracts settled and includes amounts yet to be billed to customers. Dominion and Virginia Power collect sales, consumption and consumer utility taxes and Dominion Gas collects sales taxes; however, these amounts are excluded from revenue. Dominion's customer receivables at December 31, 2014 and 2013 included $564 million and $555 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to its utility customers. Virginia Power's customer receivables at December 31, 2014 and 2013 included $407 million and $395 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers. Dominion Gas' customer receivables at December 31, 2014 and 2013 included $127 million and $106 million, respectively, of accrued unbilled revenue based on estimated amounts of natural gas delivered but not yet billed to its customers.
	The primary types of sales and service activities reported as operating revenue for Dominion are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services;
	•	Nonregulated electric sales consist primarily of sales of electricity at market-based rates and contracted fixed rates, and associated derivative activity;
	•	Regulated gas sales consist primarily of state- and FERC-regulated natural gas sales and related distribution services;
	•	Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties, gas trading and marketing revenue and associated derivative activity;
	•	Gas transportation and storage consists primarily of regulated sales of gathering, transmission, distribution and storage services. Also included are regulated gas distribution charges to retail distribution service customers opting for alternate suppliers; and
	•	Other revenue consists primarily of sales of NGL production and condensate, extracted products and associated derivative activity. Other revenue also includes miscellaneous service revenue from electric and gas distribution operations, and gas processing and handling revenue.
	The primary types of sales and service activities reported as operating revenue for Virginia Power are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales and federally-regulated wholesale electric sales and electric transmission services; and
	•	Other revenue consists primarily of miscellaneous service revenue from electric distribution operations and miscellaneous revenue from generation operations, including sales of capacity and other commodities.
	The primary types of sales and service activities reported as operating revenue for Dominion Gas are as follows:
	•	Regulated gas sales consist primarily of state- and FERC-regulated natural gas sales and related distribution services;
	•	Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices and sales of gas purchased from third parties. Revenue from sales of gas production is recognized based on actual volumes of gas sold to purchasers and is reported net of royalties;
	•	Gas transportation and storage consists primarily of regulated sales of gathering, transmission, distribution and storage services. Also included are regulated gas distribution charges to retail distribution service customers opting for alternate suppliers;
	•	NGL revenue consists primarily of sales of NGL production and condensate, extracted products and associated derivative activity; and
	•	Other revenue consists primarily of miscellaneous service revenue, gas processing and handling revenue and gathering revenue.
Electric Fuel Purchased Energy and Purchased Gas-Deferred Costs	Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs
	Where permitted by regulatory authorities, the differences between Dominion's and Virginia Power's actual electric fuel and purchased energy expenses and Dominion's and Dominion Gas' purchased gas expenses and the related levels of recovery for these expenses in current rates are deferred and matched against recoveries in future periods. The deferral of costs in excess of current period fuel rate recovery is recognized as a regulatory asset, while rate recovery in excess of current period fuel expenses is recognized as a regulatory liability.
	Of the cost of fuel used in electric generation and energy purchases to serve utility customers, approximately 84% is currently subject to deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms.
	Virtually all of Dominion Gas', Cove Point's and Hope's natural gas purchases are either subject to deferral accounting or are recovered from the customer in the same accounting period as the sale.
Income Taxes	Income Taxes
	A consolidated federal income tax return is filed for Dominion and its subsidiaries, including Virginia Power and Dominion Gas' subsidiaries. In addition, where applicable, combined income tax returns for Dominion and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed.
	Although Dominion Gas is disregarded for income tax purposes, a provision for income taxes is recognized to reflect the inclusion of its business activities in the tax returns of its parent, Dominion. Virginia Power and Dominion Gas participate in intercompany tax sharing agreements with Dominion and its subsidiaries and current income taxes are based on taxable income or loss, determined on a separate company basis.
	Under the agreements, if a subsidiary incurs a net operating loss, recognition of current income tax benefits is limited to refunds of prior year taxes obtained by the carryback of the net operating loss or to the extent the net operating loss is absorbed by the taxable income of other Dominion consolidated group members. Otherwise, the net operating loss is carried forward and is recognized as a deferred tax asset until realized.
	Accounting for income taxes involves an asset and liability approach. Deferred income tax assets and liabilities are provided, representing future effects on income taxes for temporary differences between the bases of assets and liabilities for financial reporting and tax purposes. Accordingly, deferred taxes are recognized for the future consequences of different treatments used for the reporting of transactions in financial accounting and income tax returns. The Companies establish a valuation allowance when it is more-likely-than-not that all, or a portion, of a deferred tax asset will not be realized. Where the treatment of temporary differences is different for rate-regulated operations, a regulatory asset is recognized if it is probable that future revenues will be provided for the payment of deferred tax liabilities.
	The Companies recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not to be realized, assuming that the position will be examined by tax authorities with full knowledge of all relevant information.
	If it is not more-likely-than-not that a tax position, or some portion thereof, will be sustained, the related tax benefits are not recognized in the financial statements. Unrecognized tax benefits may result in an increase in income taxes payable, a reduction of income tax refunds receivable or changes in deferred taxes. Also, when uncertainty about the deductibility of an amount is limited to the timing of such deductibility, the increase in income taxes payable (or reduction in tax refunds receivable) is accompanied by a decrease in deferred tax liabilities. Except when such amounts are presented net with amounts receivable from or amounts prepaid to tax authorities, noncurrent income taxes payable related to unrecognized tax benefits are classified in other deferred credits and other liabilities on the consolidated balance sheets and current payables are included in accrued interest, payroll and taxes on the consolidated balance sheets.
	The Companies recognize interest on underpayments and overpayments of income taxes in interest expense and other income, respectively. Penalties are also recognized in other income.
	Dominion's, Virginia Power's and Dominion Gas' interest and penalties were immaterial in 2014, 2013 and 2012.
	At December 31, 2014, Virginia Power's Consolidated Balance Sheet included $225 million of federal and state income taxes receivable, $13 million of noncurrent state income taxes receivable and $38 million of noncurrent federal and state income taxes payable.
	At December 31, 2013, Virginia Power's Consolidated Balance Sheet included $3 million of state income taxes receivable, $22 million of federal and state income taxes payable, $12 million of noncurrent state income taxes receivable and $28 million of noncurrent federal and state income taxes payable.
	At December 31, 2014, Dominion Gas' Consolidated Balance Sheet included $96 million of federal and state income taxes receivable, $14 million of state income taxes payable, $7 million of noncurrent state income taxes payable and $20 million noncurrent state income taxes receivable.
	At December 31, 2013, Dominion Gas' Consolidated Balance Sheet included $17 million of federal income taxes payable, $23 million of state income taxes payable, $1 million of state income taxes receivable, $7 million of noncurrent state income taxes payable and $20 million noncurrent state income taxes receivable.
	Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold.
Cash and Cash Equivalents	Cash and Cash Equivalents
	Current banking arrangements generally do not require checks to be funded until they are presented for payment. The following table illustrates the checks outstanding but not yet presented for payment and recorded in accounts payable for the Companies:
	Year Ended December 31,	2014	2013
	(millions)
	Dominion	$42	$38
	Virginia Power	20	21
	Dominion Gas	9	7
	For purposes of the Consolidated Statements of Cash Flows, cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less.
Derivative Instruments	Derivative Instruments
	Dominion and Virginia Power use derivative instruments such as futures, swaps, forwards, options and FTRs to manage the commodity, currency exchange and financial market risks of their business operations. Dominion Gas uses derivative instruments such as physical and financial forwards, futures and swaps to manage commodity price and interest rate risks.
	All derivatives, except those for which an exception applies, are required to be reported in the Consolidated Balance Sheets at fair value. Derivative contracts representing unrealized gain positions and purchased options are reported as derivative assets. Derivative contracts representing unrealized losses and options sold are reported as derivative liabilities. One of the exceptions to fair value accounting, normal purchases and normal sales, may be elected when the contract satisfies certain criteria, including a requirement that physical delivery of the underlying commodity is probable. Expenses and revenues resulting from deliveries under normal purchase contracts and normal sales contracts, respectively, are included in earnings at the time of contract performance.
	The Companies do not offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. Dominion had margin assets of $287 million and $620 million associated with cash collateral at December 31, 2014 and 2013, respectively. Dominion had margin liabilities of $34 million and $2 million associated with cash collateral at December 31, 2014 and 2013, respectively. Virginia Power had margin assets of $6 million and $11 million associated with cash collateral at December 31, 2014 and 2013, respectively. Virginia Power did not have any margin liabilities associated with cash collateral at December 31, 2014 or 2013. Dominion Gas did not have any margin assets or liabilities related to cash collateral at December 31, 2014 or 2013. See Note 7 for further information about derivatives.
	To manage price risk, Dominion and Virginia Power hold certain derivative instruments that are not designated as hedges for accounting purposes. However, to the extent Dominion and Virginia Power do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices, interest rates and foreign exchange rates. As part of Dominion’s strategy to market energy and manage related risks, it formerly managed a portfolio of commodity-based financial derivative instruments held for trading purposes. Dominion used established policies and procedures to manage the risks associated with price fluctuations in these energy commodities and used various derivative instruments to reduce risk by creating offsetting market positions. In the second quarter of 2013, Dominion commenced a repositioning of its producer services business. The repositioning was completed in the first quarter of 2014 and resulted in the termination of natural gas trading and certain energy marketing activities.
	Statement of Income Presentation:
	•	Derivatives Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue on a net basis.
	•	Derivatives Not Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses or interest and related charges based on the nature of the underlying risk.
	In Virginia Power's generation operations, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities for jurisdictions subject to cost-based rate regulation. Realized gains or losses on the derivative instruments are generally recognized when the related transactions impact earnings.
	DERIVATIVE INSTRUMENTS DESIGNATED AS HEDGING INSTRUMENTS
	The Companies designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. For all derivatives designated as hedges, the Companies formally document the relationship between the hedging instrument and the hedged item, as well as the risk management objective and the strategy for using the hedging instrument. The Companies assess whether the hedging relationship between the derivative and the hedged item is highly effective at offsetting changes in cash flows or fair values both at the inception of the hedging relationship and on an ongoing basis. Any change in the fair value of the derivative that is not effective at offsetting changes in the cash flows or fair values of the hedged item is recognized currently in earnings. Also, the Companies may elect to exclude certain gains or losses on hedging instruments from the assessment of hedge effectiveness, such as gains or losses attributable to changes in the time value of options or changes in the difference between spot prices and forward prices, thus requiring that such changes be recorded currently in earnings. Hedge accounting is discontinued prospectively for derivatives that cease to be highly effective hedges. For derivative instruments that are accounted for as fair value hedges or cash flow hedges, the cash flows from the derivatives and from the related hedged items are classified in operating cash flows.
	Cash Flow Hedges-A majority of the Companies' hedge strategies represents cash flow hedges of the variable price risk associated with the purchase and sale of electricity, natural gas, NGLs and other energy-related products. The Companies also use foreign currency contracts to hedge the variability in foreign exchange rates and interest rate swaps to hedge their exposure to variable interest rates on long-term debt. For transactions in which the Companies are hedging the variability of cash flows, changes in the fair value of the derivatives are reported in AOCI, to the extent they are effective at offsetting changes in the hedged item. Any derivative gains or losses reported in AOCI are reclassified to earnings when the forecasted item is included in earnings, or earlier, if it becomes probable that the forecasted transaction will not occur. For cash flow hedge transactions, hedge accounting is discontinued if the occurrence of the forecasted transaction is no longer probable.
	Dominion entered into interest rate derivative instruments to hedge its forecasted interest payments related to planned debt issuances in 2013 and 2014. These interest rate derivatives were designated by Dominion as cash flow hedges in 2012 and 2013, prior to the formation of Dominion Gas. For the purposes of the Dominion Gas financial statements, the derivative balances, AOCI balance, and any income statement impact related to these interest rate derivative instruments entered into by Dominion have been, and will continue to be, included in the Dominion Gas' Consolidated Financial Statements as the forecasted interest payments related to the debt issuances will now occur at Dominion Gas.
	Fair Value Hedges-Dominion also uses fair value hedges to mitigate the fixed price exposure inherent in certain firm commodity commitments and commodity inventory. In addition, Dominion and Virginia Power have designated interest rate swaps as fair value hedges on certain fixed rate long-term debt to manage interest rate exposure. For fair value hedge transactions, changes in the fair value of the derivative are generally offset currently in earnings by the recognition of changes in the hedged item's fair value. Derivative gains and losses from the hedged item are reclassified to earnings when the hedged item is included in earnings, or earlier, if the hedged item no longer qualifies for hedge accounting. Hedge accounting is discontinued if the hedged item no longer qualifies for hedge accounting. See Note 6 for further information about fair value measurements and associated valuation methods for derivatives. See Note 7 for further information on derivatives.
Property, Plant and Equipment	Property, Plant and Equipment
	Property, plant and equipment is recorded at lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs such as asset retirement costs, capitalized interest and, for certain operations subject to cost-of-service rate regulation, AFUDC and overhead costs. The cost of repairs and maintenance, including minor additions and replacements, is generally charged to expense as it is incurred.
	In 2014, 2013 and 2012, Dominion capitalized interest costs and AFUDC to property, plant and equipment of $80 million, $66 million and $91 million, respectively. In 2014, 2013 and 2012, Virginia Power capitalized AFUDC to property, plant and equipment of $39 million, $33 million and $31 million, respectively. In 2014, 2013 and 2012, Dominion Gas capitalized AFUDC to property, plant and equipment of $1 million, $5 million and $23 million, respectively.
	Under Virginia law, certain Virginia jurisdictional projects qualify for current recovery of AFUDC through rate adjustment clauses. AFUDC on these projects is calculated and recorded as a regulatory asset and is not capitalized to property, plant and equipment. In 2014, 2013 and 2012, Virginia Power recorded $8 million, $32 million and $37 million of AFUDC related to these projects, respectively.
	For property subject to cost-of-service rate regulation, including Virginia Power electric distribution, electric transmission, and generation property, Dominion Gas natural gas distribution and transmission property, and for certain Dominion natural gas property, the undepreciated cost of such property, less salvage value, is generally charged to accumulated depreciation at retirement. Cost of removal collections from utility customers not representing AROs are recorded as regulatory liabilities. For property subject to cost-of-service rate regulation that will be abandoned significantly before the end of its useful life, the net carrying value is reclassified from plant-in-service when it becomes probable it will be abandoned.
	For property that is not subject to cost-of-service rate regulation, including nonutility property, cost of removal not associated with AROs is charged to expense as incurred. The Companies also record gains and losses upon retirement based upon the difference between the proceeds received, if any, and the property's net book value at the retirement date.
	Depreciation of property, plant and equipment is computed on the straight-line method based on projected service lives. The Companies' average composite depreciation rates on utility property, plant and equipment are as follows:
	Year Ended December 31,	2014	2013	2012
	(percent)
	Dominion
	Generation	2.66	2.71	2.62
	Transmission	2.38	2.36	2.17
	Distribution	3.12	3.13	3.17
	Storage	2.39	2.43	2.59
	Gas gathering and processing	2.81	2.39	2.49
	General and other	3.62	3.82	4.55
	Virginia Power
	Generation	2.66	2.71	2.62
	Transmission	2.34	2.28	1.98
	Distribution	3.34	3.33	3.32
	General and other	3.29	3.51	4.32
	Dominion Gas
	Transmission	2.4	2.43	2.35
	Distribution	2.47	2.5	2.66
	Storage	2.4	2.43	2.58
	Gas gathering and processing	2.82	2.39	2.5
	General and other	5.77	5.93	6.09
	In 2013, Virginia Power revised its depreciation rates to reflect the results of a new depreciation study. This change resulted in an increase of $19 million ($12 million after-tax) in depreciation and amortization expense in Virginia Power's Consolidated Statements of Income.
	In 2014, Virginia Power also made a one-time adjustment to depreciation expense as ordered by the Virginia Commission. This adjustment resulted in an increase of $38 million ($23 million after-tax) in depreciation and amortization expense in Virginia Power’s Consolidated Statements of Income.
	In 2013, Dominion Gas revised the depreciation rates for East Ohio to reflect the results of a new depreciation study. This change resulted in a decrease of $8 million ($5 million after-tax) in depreciation and amortization expense in Dominion Gas' Consolidated Statements of Income.
	Dominion's nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives:
	Asset	Estimated Useful Lives
	Merchant generation-nuclear	44 years
	Merchant generation-other	15-36 years
	General and other	5-59 years
	Depreciation and amortization related to Virginia Power's and Dominion Gas' nonutility property, plant and equipment and E&P properties was immaterial for the years ended December 31, 2014, 2013 and 2012.
	Nuclear fuel used in electric generation is amortized over its estimated service life on a units-of-production basis. Dominion and Virginia Power report the amortization of nuclear fuel in electric fuel and other energy-related purchases expense in their Consolidated Statements of Income and in depreciation and amortization in their Consolidated Statements of Cash Flows.
Long-Lived and Intangible Assets	Long-Lived and Intangible Assets
	The Companies perform an evaluation for impairment whenever events or changes in circumstances indicate that the carrying amount of long-lived assets or intangible assets with finite lives may not be recoverable. A long-lived or intangible asset is written down to fair value if the sum of its expected future undiscounted cash flows is less than its carrying amount. Intangible assets with finite lives are amortized over their estimated useful lives. See Note 6 for a discussion of impairments related to certain long-lived assets and intangible assets with finite lives.
Regulatory Assets and Liabilities	Regulatory Assets and Liabilities
	The accounting for Dominion's and Dominion Gas' regulated gas and Virginia Power's regulated electric operations differs from the accounting for nonregulated operations in that they are required to reflect the effect of rate regulation in their Consolidated Financial Statements. For regulated businesses subject to federal or state cost-of-service rate regulation, regulatory practices that assign costs to accounting periods may differ from accounting methods generally applied by nonregulated companies. When it is probable that regulators will permit the recovery of current costs through future rates charged to customers, these costs that otherwise would be expensed by nonregulated companies are deferred as regulatory assets. Likewise, regulatory liabilities are recognized when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have yet to be incurred. Generally, regulatory assets and liabilities are amortized into income over the period authorized by the regulator.
	The Companies evaluate whether or not recovery of their regulatory assets through future rates is probable and make various assumptions in their analyses. The expectations of future recovery are generally based on orders issued by regulatory commissions, legislation or historical experience, as well as discussions with applicable regulatory authorities and legal counsel. If recovery of a regulatory asset is determined to be less than probable, it will be written off in the period such assessment is made.
Asset Retirement Obligations	Asset Retirement Obligations
	The Companies recognize AROs at fair value as incurred or when sufficient information becomes available to determine a reasonable estimate of the fair value of future retirement activities to be performed. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. At least annually, the Companies evaluate the key assumptions underlying their AROs including estimates of the amounts and timing of future cash flows associated with retirement activities. AROs are adjusted when significant changes in these assumptions are identified. Dominion and Dominion Gas report accretion of AROs and depreciation on asset retirement costs associated with their natural gas pipeline and storage well assets as an adjustment to the related regulatory liabilities when revenue is recoverable from customers for AROs. Virginia Power reports accretion of AROs and depreciation on asset retirement costs associated with decommissioning its nuclear power stations as an adjustment to the regulatory liability for certain jurisdictions. Accretion of all other AROs and depreciation of all other asset retirement costs is reported in other operations and maintenance expense and depreciation expense in the Consolidated Statements of Income.
Debt Issuance Costs	Debt Issuance Costs
	The Companies defer and amortize debt issuance costs and debt premiums or discounts over the expected lives of the respective debt issues, considering maturity dates and, if applicable, redemption rights held by others. Deferred debt issuance costs are recorded as an asset and classified in other current assets and other deferred charges and other assets in the Consolidated Balance Sheets. Unamortized costs associated with redemptions of debt securities prior to stated maturity dates are generally recognized and recorded in interest expense immediately. As permitted by regulatory authorities, gains or losses resulting from the refinancing of debt allocable to utility operations subject to cost-based rate regulation are deferred and amortized over the lives of the new issuances.
Investments	Investments
	MARKETABLE EQUITY AND DEBT SECURITIES
	Dominion accounts for and classifies investments in marketable equity and debt securities as trading or available-for-sale securities. Virginia Power classifies investments in marketable equity and debt securities as available-for-sale securities.
	•	Trading securities include marketable equity and debt securities held by Dominion in rabbi trusts associated with certain deferred compensation plans. These securities are reported in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income.
	•	Available-for-sale securities include all other marketable equity and debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any other-than-temporary impairments) on investments held in Virginia Power's nuclear decommissioning trusts are recorded to a regulatory liability for certain jurisdictions subject to cost-based regulation. For all other available-for-sale securities, including those held in Dominion's merchant generation nuclear decommissioning trusts, net realized gains and losses (including any other-than-temporary impairments) are included in other income and unrealized gains and losses are reported as a component of AOCI, after-tax.
	In determining realized gains and losses for marketable equity and debt securities, the cost basis of the security is based on the specific identification method.
	NON-MARKETABLE INVESTMENTS
	The Companies account for illiquid and privately held securities for which market prices or quotations are not readily available under either the equity or cost method. Non-marketable investments include:
	•	Equity method investments when the Companies have the ability to exercise significant influence, but not control, over the investee. Dominion's investments are included in investments in equity method affiliates and Virginia Power's investments are included in other investments in their Consolidated Balance Sheets. The Companies record equity method adjustments in other income in the Consolidated Statements of Income including: their proportionate share of investee income or loss, gains or losses resulting from investee capital transactions, amortization of certain differences between the carrying value and the equity in the net assets of the investee at the date of investment and other adjustments required by the equity method.
	•	Cost method investments when Dominion and Virginia Power do not have the ability to exercise significant influence over the investee. Dominion's and Virginia Power's investments are included in other investments and nuclear decommissioning trust funds.
	OTHER-THAN-TEMPORARY IMPAIRMENT
	Dominion and Virginia Power periodically review their investments to determine whether a decline in fair value should be considered other-than-temporary. If a decline in fair value of any security is determined to be other-than-temporary, the security is written down to its fair value at the end of the reporting period.
	Decommissioning Trust Investments-Special Considerations
	•	The recognition provisions of the FASB's other-than-temporary impairment guidance apply only to debt securities classified as available-for-sale or held-to-maturity, while the presentation and disclosure requirements apply to both debt and equity securities.
	•	Debt Securities- Using information obtained from their nuclear decommissioning trust fixed-income investment managers, Dominion and Virginia Power record in earnings any unrealized loss for a debt security when the manager intends to sell the debt security or it is more-likely-than-not that the manager will have to sell the debt security before recovery of its fair value up to its cost basis. If that is not the case, but the debt security is deemed to have experienced a credit loss, Dominion and Virginia Power record the credit loss in earnings and any remaining portion of the unrealized loss in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors.
	•	Equity securities and other investments- Dominion's and Virginia Power's method of assessing other-than-temporary declines requires demonstrating the ability to hold individual securities for a period of time sufficient to allow for the anticipated recovery in their market value prior to the consideration of the other criteria mentioned above. Since Dominion and Virginia Power have limited ability to oversee the day-to-day management of nuclear decommissioning trust fund investments, they do not have the ability to ensure investments are held through an anticipated recovery period. Accordingly, they consider all equity and other securities as well as non-marketable investments held in nuclear decommissioning trusts with market values below their cost bases to be other-than-temporarily impaired.
Inventories	Inventories
	Materials and supplies and fossil fuel inventories are valued primarily using the weighted-average cost method. Stored gas inventory for Dominion Gas used in East Ohio gas distribution operations is valued using the LIFO method. Under the LIFO method, stored gas inventory was valued at $12 million and $7 million at December 31, 2014 and December 31, 2013, respectively. Based on the average price of gas purchased during 2014 and 2013, the cost of replacing the current portion of stored gas inventory exceeded the amount stated on a LIFO basis by approximately $98 million and $77 million, respectively. Stored gas inventory for Dominion held by Hope and certain nonregulated gas operations is valued using the weighted-average cost method.
Gas Imbalances	Gas Imbalances
	Natural gas imbalances occur when the physical amount of natural gas delivered from, or received by, a pipeline system or storage facility differs from the contractual amount of natural gas delivered or received. Dominion and Dominion Gas value these imbalances due to, or from, shippers and operators at an appropriate index price at period end, subject to the terms of its tariff for regulated entities. Imbalances are primarily settled in-kind. Imbalances due to Dominion and Dominion Gas from other parties are reported in other current assets and imbalances that Dominion and Dominion Gas owe to other parties are reported in other current liabilities in the Consolidated Balance Sheets.
Goodwill	Goodwill
	Dominion and Dominion Gas evaluate goodwill for impairment annually as of April 1 and whenever an event occurs or circumstances change in the interim that would more-likely-than-not reduce the fair value of a reporting unit below its carrying amount.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Schedule of Checks Outstanding but Not Yet Presented for Payment	The following table illustrates the checks outstanding but not yet presented for payment and recorded in accounts payable for the Companies:
	Year Ended December 31,	2014	2013
	(millions)
	Dominion	$42	$38
	Virginia Power	20	21
	Dominion Gas	9	7
Schedule of Depreciation Rates	The Companies' average composite depreciation rates on utility property, plant and equipment are as follows:
	Year Ended December 31,	2014	2013	2012
	(percent)
	Dominion
	Generation	2.66	2.71	2.62
	Transmission	2.38	2.36	2.17
	Distribution	3.12	3.13	3.17
	Storage	2.39	2.43	2.59
	Gas gathering and processing	2.81	2.39	2.49
	General and other	3.62	3.82	4.55
	Virginia Power
	Generation	2.66	2.71	2.62
	Transmission	2.34	2.28	1.98
	Distribution	3.34	3.33	3.32
	General and other	3.29	3.51	4.32
	Dominion Gas
	Transmission	2.4	2.43	2.35
	Distribution	2.47	2.5	2.66
	Storage	2.4	2.43	2.58
	Gas gathering and processing	2.82	2.39	2.5
	General and other	5.77	5.93	6.09
Schedule of Estimated Useful Life	Dominion's nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives:
	Asset	Estimated Useful Lives
	Merchant generation-nuclear	44 years
	Merchant generation-other	15-36 years
	General and other	5-59 years

Acquisitions_and_Dispositions_

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2014
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 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:
	Year Ended December 31,	2013				2012
	(millions)
	Operating revenue	$	304			$	258
	Loss before income taxes	(135		)	(1)	(1,768		)	(2)
	(1) Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013.
	(2) Includes a long-lived asset impairment charge of $1.6 billion.
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 Disclosures	The following table presents selected information regarding the results of operations of Salem Harbor and State Line, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
	Year Ended December 31,	2012
	(millions)
	Operating revenue	$	57
	Loss before income taxes	(49		)

Operating_Revenue_Tables

Operating Revenue (Tables)	12 Months Ended
	Dec. 31, 2014
Regulated and Unregulated Operating Revenue [Abstract]
Operating Revenue, Table	The Companies' operating revenue consists of the following:
	Year Ended December 31,	2014		2013		2012
	(millions)
	Dominion
	Electric sales:
	Regulated	$	7,460	$	7,193	$	7,102
	Nonregulated	1,839		2,511		2,483
	Gas sales:
	Regulated	334		323		250
	Nonregulated	751		930		1,071
	Gas transportation and storage	1,543		1,535		1,401
	Other	509		628		528
	Total operating revenue	$	12,436	$	13,120	$	12,835
	Virginia Power
	Regulated electric sales	$	7,460	$	7,193	$	7,102
	Other	119		102		124
	Total operating revenue	$	7,579	$	7,295	$	7,226
	Dominion Gas
	Gas sales:
	Regulated	$	209	$	202	$	138
	Nonregulated	26		32		28
	Gas transportation and storage	1,353		1,338		1,188
	NGL revenue	212		292		275
	Other	98		73		48
	Total operating revenue	$	1,898	$	1,937	$	1,677

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income tax expense for continuing operations including noncontrolling interests	Details of income tax expense for continuing operations including noncontrolling interests were as follows:
		Dominion									Virginia Power									Dominion Gas
	Year Ended December 31,	2014			2013			2012			2014			2013			2012			2014		2013			2012
	(millions)
	Current:
	Federal	$	(11	)	$	317		$	43		$	85		$	357		$	70		$	86	$	158		$	(8	)
	State	14			110			84			67			62			81			32		41			2
	Total current expense (benefit)	3			427			127			152			419			151			118		199			(6		)
	Deferred:
	Federal
	Taxes before operating loss carryforwards and investment tax credits	956			563			645			381			224			482			192		92			257
	Tax benefit of operating loss carryforwards	(352		)	(18		)	—			—			—			—			—		—			—
	Investment tax credits	(152		)	(48		)	—			—			—			—			—		—			—
	State	(2		)	(31		)	40			16			17			21			24		10			37
	Total deferred expense	450			466			685			397			241			503			216		102			294
	Amortization of deferred investment tax credits	(1		)	(1		)	(1		)	(1		)	(1		)	(1		)	—		—			—
	Total income tax expense	$	452		$	892		$	811		$	548		$	659		$	653		$	334	$	301		$	288
Effective income tax	For continuing operations including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to the Companies' effective income tax rate as follows:
		Dominion						Virginia Power						Dominion Gas
	Year Ended December 31,	2014		2013		2012		2014		2013		2012		2014		2013		2012
	U.S. statutory rate	35	%	35	%	35	%	35	%	35	%	35	%	35	%	35	%	35	%
	Increases (reductions) resulting from:
	State taxes, net of federal benefit	—		2.1		4.2		3.8		3.1		3.9		4.4		4.3		3.4
	Investment tax credits	(8.6	)	(1.8	)	—		—		—		—		—		—		—
	Production tax credits	(1.2	)	(0.6	)	(0.5	)	(0.6	)	(0.2	)	—		—		—		—
	Valuation allowances	0.7		(0.1	)	(0.7	)	—		—		—		—		—		—
	AFUDC - equity	—		(0.6	)	(0.9	)	—		(0.8	)	(0.9	)	—		(0.1	)	(0.6	)
	Employee stock ownership plan deduction	(0.9	)	(0.6	)	(0.7	)	—		—		—		—		—		—
	Other, net	0.4		(0.4	)	(0.6	)	0.8		(0.4	)	0.3		0.1		0.3		0.7
	Effective tax rate	25.4	%	33	%	35.8	%	39	%	36.7	%	38.3	%	39.5	%	39.5	%	38.5	%
The Companies deferred income taxes components	The Companies' deferred income taxes consist of the following:
		Dominion						Virginia Power						Dominion Gas
	At December 31,	2014			2013			2014			2013			2014			2013
	(millions)
	Deferred income taxes:
	Total deferred income tax assets	$	2,023		$	2,142		$	500		$	462		$	227		$	216
	Total deferred income tax liabilities	8,663			8,463			4,915			4,498			2,289			2,103
	Total net deferred income tax liabilities	$	6,640		$	6,321		$	4,415		$	4,036		$	2,062		$	1,887
	Total deferred income taxes:
	Plant and equipment, primarily depreciation method and basis differences	$	5,895		$	5,383		$	3,965		$	3,628		$	1,417		$	1,266
	Nuclear decommissioning	1,241			1,136			474			441			—			—
	Deferred state income taxes	659			606			299			285			207			182
	Federal benefit of deferred state income taxes	(231		)	(212		)	(105		)	(100		)	(72		)	(64		)
	Deferred fuel, purchased energy and gas costs	27			(33		)	18			(50		)	7			13
	Pension benefits	272			435			(77		)	(52		)	567			522
	Other postretirement benefits	(17		)	(78		)	13			(3		)	(12		)	(13		)
	Loss and credit carryforwards	(1,434		)	(797		)	(116		)	(106		)	(10		)	(10		)
	Valuation allowances	87			69			—			—			—			—
	Partnership basis differences	304			125			—			—			42			42
	Other	(163		)	(313		)	(56		)	(7		)	(84		)	(51		)
	Total net deferred income tax liabilities	$	6,640		$	6,321		$	4,415		$	4,036		$	2,062		$	1,887
Reconciliation of changes in the Companies unrecognized tax benefits	A reconciliation of changes in the Companies' unrecognized tax benefits follows:
		Dominion									Virginia Power									Dominion Gas
		2014			2013			2012			2014			2013			2012			2014		2013			2012
	(millions)
	Balance at January 1	$	222		$	293		$	347		$	39		$	57		$	114		$	29	$	30		$	30
	Increases-prior period positions	24			17			28			2			12			4			—		—			—
	Decreases-prior period positions	(26		)	(99		)	(106		)	(16		)	(42		)	(80		)	—		(1		)	—
	Increases-current period positions	16			30			43			11			14			24			—		—			—
	Decreases-current period positions	—			(5		)	—			—			—			—			—		—			—
	Settlements with tax authorities	—			(2		)	(4		)	—			(2		)	(4		)	—		—			—
	Expiration of statutes of limitations	(91		)	(12		)	(15		)	—			—			(1		)	—		—			—
	Balance at December 31	$	145		$	222		$	293		$	36		$	39		$	57		$	29	$	29		$	30
Earliest tax year remaining	For each of the major states in which Dominion operates, the earliest tax year remaining open for examination is as follows:
	State	Earliest Open Tax Year
	Pennsylvania(1)	2010
	Connecticut	2011
	Virginia(2)	2011
	West Virginia(1)	2011
	New York(1)	2007
	-1	Considered a major state for Dominion Gas' operations.
	-2	Considered a major state for Virginia Power's operations.
Schedule of Components of Income Tax Expense (Benefit) from Discontinued Operations	Details of income tax expense for Dominion's discontinued operations were as follows:
	Year Ended December 31,	2013		2012
	(millions)
	Current:
	Federal	(274	)	(248	)
	State	(41	)	(6	)
	Total current benefit	(315	)	(254	)
	Deferred:
	Federal	232		(368	)
	State	40		(70	)
	Total deferred expense (benefit)	272		(438	)
	Total income tax benefit	(43	)	(692	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Option, Quantitative Disclosures	The following table presents Dominion's and Dominion Gas' quantitative information about Level 3 fair value measurements at December 31, 2014. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility and credit spreads.
		Fair Value (millions)			Valuation Techniques	Unobservable Input		Range		Weighted Average(1)
	Assets:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	74		Discounted Cash Flow	Market Price (per Dth)	(4)	(2) - 11		(1	)
						Credit spread	(6)	1% - 5%		2	%
	FTRs	44			Discounted Cash Flow	Market Price (per MWh)	(4)	(1) - 21		3
	NGLs(3)	2			Discounted Cash Flow	Market Price (per Gal)	(4)	0 - 2		1
	Physical and Financial Options:
	Natural Gas	5			Option Model	Market Price (per Dth)	(4)	4-Feb		3
						Price Volatility	(5)	19% - 67%		33	%
	Total assets	$	125
	Liabilities:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	12		Discounted Cash Flow	Market Price (per Dth)	(4)	(2) - 4		2
	FTRs	4			Discounted Cash Flow	Market Price (per MWh)	(4)	(21) - 21		—
	Physical and Financial Options:
	Natural Gas	2			Option Model	Market Price (per Dth)	(4)	4-Feb		3
						Price Volatility	(5)	19% - 67%		33	%
	Total liabilities	$	18
	-1	Averages weighted by volume.
	-2	Includes basis.
	-3	Information represents Dominion Gas quantitative information about Level 3 fair value measurements.
	-4	Represents market prices beyond defined terms for Levels 1 and 2.
	-5	Represents volatilities unrepresented in published markets.
	-6	Represents credit spreads unrepresented in published markets.
Fair Value, Option, Qualitative Disclosures Related to Election	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)
	Credit spread	Asset	Increase (decrease)	Loss (gain)
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 December 31, 2014
	Assets:
	Derivatives:
	Commodity	$	3		$	567		$	125		$	695
	Interest rate	—			24			—			24
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	2,669			—			—			2,669
	Other	6			—			—			6
	Non-U.S.:
	Large Cap	12			—			—			12
	Fixed Income:
	Corporate debt instruments	—			441			—			441
	U.S. Treasury securities and agency debentures	419			190			—			609
	State and municipal	—			395			—			395
	Other	—			74			—			74
	Cash equivalents and other	3			10			—			13
	Total assets	$	3,112		$	1,701		$	125		$	4,938
	Liabilities:
	Derivatives:
	Commodity	$	3		$	571		$	18		$	592
	Interest rate	—			202			—			202
	Total liabilities	$	3		$	773		$	18		$	794
	At December 31, 2013
	Assets:
	Derivatives:
	Commodity	$	3		$	718		$	32		$	753
	Interest rate	—			137			—			137
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	2,417			—			—			2,417
	Other	79			—			—			79
	Non-U.S.:
	Large Cap	13			—			—			13
	Fixed Income:
	Corporate debt instruments	—			345			—			345
	U.S. Treasury securities and agency debentures	415			175			—			590
	State and municipal	—			343			—			343
	Other	—			3			—			3
	Cash equivalents and other	—			103			—			103
	Restricted cash equivalents	—			8			—			8
	Total assets	$	2,927		$	1,832		$	32		$	4,791
	Liabilities:
	Derivatives:
	Commodity	$	3		$	1,051		$	48		$	1,102
	Total liabilities	$	3		$	1,051		$	48		$	1,102
	-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:
		2014			2013			2012
	(millions)
	Balance at January 1,	$	(16	)	$	25		$	(71	)
	Total realized and unrealized gains (losses):
	Included in earnings	97			(9		)	(15		)
	Included in other comprehensive income (loss)	7			1			101
	Included in regulatory assets/liabilities	109			(9		)	30
	Settlements	(88		)	(23		)	47
	Transfers out of Level 3	(2		)	(1		)	(67		)
	Balance at December 31,	$	107		$	(16	)	$	25
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	$	6		$	—		$	42
Fair Value, Unobservable Inputs, Gain (Loss) Included In Earnings	The following table presents Dominion's gains and losses included in earnings in the Level 3 fair value category:
		Operating			Electric Fuel			Purchased			Total
		Revenue			and Energy			Gas
					Purchases
	(millions)
	Year Ended December 31, 2014
	Total gains (losses) included in earnings	$	4		$	97		$	(4	)	$	97
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	4			1			1			6
	Year Ended December 31, 2013
	Total gains (losses) included in earnings	$	11		$	(19	)	$	(1	)	$	(9	)
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	1			—			(1		)	—
	Year Ended December 31, 2012
	Total gains (losses) included in earnings	$	35		$	(50	)	$	—		$	(15	)
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	42			—			—			42
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	:
	At December 31,	2014						2013
		Carrying			Estimated			Carrying			Estimated
		Amount			Fair Value(1)			Amount			Fair Value(1)
	(millions)
	Dominion
	Long-term debt, including securities due within one year(2)	$	19,723		$	21,881		$	18,396		$	19,887
	Junior subordinated notes(3)	1,374			1,396			1,373			1,394
	Remarketable subordinated notes(3)	2,083			2,362			1,080			1,192
	Subsidiary preferred stock(4)	—			—			257			261
	Virginia Power
	Long-term debt, including securities due within one year(3)	$	8,937		$	10,293		$	8,032		$	8,897
	Preferred stock(4)	—			—			257			261
	Dominion Gas
	Long-term debt(3)	$	2,594		$	2,672		$	1,198		$	1,169
	-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/or premium. At December 31, 2014, and 2013, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of approximately $19 million and $55 million, respectively.
	-3	Carrying amount includes amounts which represent the unamortized discount and/or premium.
	-4	Includes deferred issuance expenses of $2 million at December 31, 2013
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Option, Quantitative Disclosures	The following table presents Virginia Power's quantitative information about Level 3 fair value measurements at December 31, 2014. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads.
		Fair Value (millions)			Valuation Techniques	Unobservable Input		Range		Weighted Average(1)
	Assets:
	Physical and Financial Forwards and Futures:
	FTRs	$	44		Discounted Cash Flow	Market Price (per MWh)	(3)	(1) - 21		3
	Natural gas(2)	62			Discounted Cash Flow	Market Price (per Dth)	(3)	(2) - 7		(1	)
						Credit spread	(4)	1% - 5%		2	%
	Total assets	$	106
	Liabilities:
	Physical and Financial Forwards and Futures:
	FTRs	$	4		Discounted Cash Flow	Market Price (per MWh)	(3)	(21) - 21		—
	Total liabilities	$	4
	-1	Averages weighted by volume.
	-2	Includes basis.
	-3	Represents market prices beyond defined terms for Levels 1 and 2.
	-4	Represents credit spreads unrepresented in published markets.
Fair Value, Option, Qualitative Disclosures Related to Election	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)
	Credit spread	Asset	Increase (decrease)	Loss (gain)
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 December 31, 2014
	Assets:
	Derivatives:
	Commodity	$	—		$	7		$	106		$	113
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	1,157			—			—			1,157
	Fixed Income:
	Corporate debt instruments	—			250			—			250
	U.S. Treasury securities and agency debentures	137			61			—			198
	State and municipal	—			211			—			211
	Other	—			23			—			23
	Total assets	$	1,294		$	552		$	106		$	1,952
	Liabilities:
	Derivatives:
	Commodity	$	—		$	11		$	4		$	15
	Interest rate	—			72			—			72
	Total liabilities	$	—		$	83		$	4		$	87
	At December 31, 2013
	Assets:
	Derivatives:
	Commodity	$	—		$	3		$	2		$	5
	Interest rate	—			48			—			48
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	1,021			—			—			1,021
	Other	36			—			—			36
	Fixed Income:
	Corporate debt instruments	—			191			—			191
	U.S. Treasury securities and agency debentures	146			66			—			212
	State and municipal	—			164			—			164
	Cash equivalents and other	—			31			—			31
	Restricted cash equivalents	—			8			—			8
	Total assets	$	1,203		$	511		$	2		$	1,716
	Liabilities:
	Derivatives:
	Commodity	$	—		$	3		$	9		$	12
	Total liabilities	$	—		$	3		$	9		$	12
	-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:
		2014			2013			2012
	(millions)
	Balance at January 1,	$	(7	)	$	2		$	(28	)
	Total realized and unrealized gains (losses):
	Included in earnings	96			(17		)	(50		)
	Included in regulatory assets/liabilities	109			(9		)	30
	Settlements	(96		)	17			50
	Balance at December 31,	$	102		$	(7	)	$	2
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, by Balance Sheet Grouping	The following table presents Dominion Gas' assets and liabilities for commodity and interest rate derivatives 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 December 31, 2014
	Assets:
	Commodity	$	—		$	—		$	2		$	2
	Total assets	$	—		$	—		$	2		$	2
	Liabilities:
	Interest rate	$	—		$	9		$	—		$	9
	Total liabilities	$	—		$	9		$	—		$	9
	At December 31, 2013
	Assets:
	Commodity	$	—		$	—		$	6		$	6
	Interest rate	—			34			—			34
	Total assets	$	—		$	34		$	6		$	40
	Liabilities:
	Commodity	$	—		$	13		$	12		$	25
	Total liabilities	$	—		$	13		$	12		$	25
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation	The following table presents the net change in Dominion Gas' derivative assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:
		2014			2013			2012
	(millions)
	Balance at January 1,	$	(6	)	$	(12	)	$	(98	)
	Total realized and unrealized gains (losses):
	Included in earnings	2			1			(15		)
	Included in other comprehensive income (loss)	10			3			86
	Settlements	(4		)	2			15
	Balance at December 31,	$	2		$	(6	)	$	(12	)

Derivatives_and_Hedge_Accounti1

Derivatives and Hedge Accounting Activities (Tables)	12 Months Ended
	Dec. 31, 2014
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:
		31-Dec-14									31-Dec-13
		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	$	24		$	—		$	24		$	137	$	—	$	137
	Commodity contracts:
	Over-the-counter	382			—			382			240		—		240
	Exchange	298			—			298			506		—		506
	Total derivatives, subject to a master netting or similar arrangement	704			—			704			883		—		883
	Total derivatives, not subject to a master netting or similar arrangement	15			—			15			7		—		7
	Total	$	719		$	—		$	719		$	890	$	—	$	890
					31-Dec-14										31-Dec-13
					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	$	24		$	16		$	—		$	8	$	137	$	—	$	—	$	137
	Commodity contracts:
	Over-the-counter	382			34			34			314		240		63		—		177
	Exchange	298			298			—			—		506		505		—		1
	Total	$	704		$	348		$	34		$	322	$	883	$	568	$	—	$	315
Offsetting Liabilities
		31-Dec-14									31-Dec-13
		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	$	202		$	—		$	202		$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	87			—			87			262		—		262
	Exchange	493			—			493			838		—		838
	Total derivatives, subject to a master netting or similar arrangement	782			—			782			1,100		—		1,100
	Total derivatives, not subject to a master netting or similar arrangement	12			—			12			2		—		2
	Total	$	794		$	—		$	794		$	1,102	$	—	$	1,102
					31-Dec-14										31-Dec-13
					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	$	202		$	16		$	—		$	186	$	—	$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	87			34			1			52		262		63		69		130
	Exchange	493			298			195			—		838		505		333		—
	Total	$	782		$	348		$	196		$	238	$	1,100	$	568	$	402	$	130
Volumes of Derivatives	The following table presents the volume of Dominion's derivative activity as of December 31, 2014. 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)	52			13
	Basis	227			575
	Electricity (MWh):
	Fixed price	14,689,432			6,148,800
	FTRs	35,786,150			—
	Capacity (MW)	10,700			7,600
	Liquids (Gals)(2)	39,984,000			1,260,000
	Interest rate	$	1,300,000,000		$	4,450,000,000
	-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 December 31, 2014:
		AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum
		After-Tax						Term
	(millions)
	Commodities:
	Gas	$	(8	)	$	(7	)	27 months
	Electricity	56			46			24 months
	Other	—			—			17 months
	Interest rate	(226		)	(6		)	384 months
	Total	$	(178	)	$	33
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following tables present the fair values of Dominion's derivatives and where they are presented in its Consolidated Balance Sheets:
		Fair Value  -			Fair Value -			Total
		Derivatives			Derivatives			Fair
		under			not under			Value
		Hedge			Hedge
		Accounting			Accounting
	(millions)
	At December 31, 2014
	ASSETS
	Current Assets
	Commodity	$	281		$	242		$	523
	Interest rate	13			—			13
	Total current derivative assets	294			242			536
	Noncurrent Assets
	Commodity	71			101			172
	Interest rate	11			—			11
	Total noncurrent derivative assets(1)	82			101			183
	Total derivative assets	$	376		$	343		$	719
	LIABILITIES
	Current Liabilities
	Commodity	$	224		$	267		$	491
	Interest rate	100			—			100
	Total current derivative liabilities	324			267			591
	Noncurrent Liabilities
	Commodity	55			46			101
	Interest rate	102			—			102
	Total noncurrent derivative liabilities(2)	157			46			203
	Total derivative liabilities	$	481		$	313		$	794
	At December 31, 2013
	ASSETS
	Current Assets
	Commodity	$	49		$	522		$	571
	Interest rate	116			—			116
	Total current derivative assets	165			522			687
	Noncurrent Assets
	Commodity	28			154			182
	Interest rate	21			—			21
	Total noncurrent derivative assets(1)	49			154			203
	Total derivative assets	$	214		$	676		$	890
	LIABILITIES
	Current Liabilities
	Commodity	$	267		$	561		$	828
	Total current derivative liabilities	267			561			828
	Noncurrent Liabilities
	Commodity	119			155			274
	Total noncurrent derivative liabilities(2)	119			155			274
	Total derivative liabilities	$	386		$	716		$	1,102
	-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.
Derivative Instruments Gain (Loss) by Hedging Relationship by Income Statement Location	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	Amount of			Amount of			Increase
	relationships	Gain (Loss)			Gain (Loss)			(Decrease)
		Recognized			Reclassified			in
		in AOCI on			from AOCI			Derivatives
		Derivatives			to Income			Subject to
		(Effective						Regulatory
		Portion)(1)						Treatment(2)
	(millions)
	Year Ended December 31, 2014
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	(130	)
	Purchased gas				(13		)
	Electric fuel and other energy-related purchases				7
	Total commodity	$	245		$	(136	)	$	(4	)
	Interest rate(3)	(208		)	(16		)	(81		)
	Total	$	37		$	(152	)	$	(85	)
	Year Ended December 31, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	(58	)
	Purchased gas				(47		)
	Electric fuel and other energy-related purchases				(10		)
	Total commodity	$	(481	)	$	(115	)	$	5
	Interest rate(3)	77			(15		)	81
	Total	$	(404	)	$	(130	)	$	86
	Year Ended December 31, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	188
	Purchased gas				(75		)
	Electric fuel and other energy-related purchases				(17		)
	Total commodity	$	71		$	96		$	10
	Interest rate(3)	(84		)	(2		)	(35		)
	Total	$	(13	)	$	94		$	(25	)
	-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
	Derivatives not designated as hedging	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	instruments
	Year Ended December 31,	2014			2013			2012
	(millions)
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue	$	(310	)	$	(45	)	$	168
	Purchased gas	(51		)	(9		)	(14		)
	Electric fuel and other energy-related purchases	113			(29		)	(40		)
	Interest rate(2)	—			—			17
	Total	$	(248	)	$	(83	)	$	131
	-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:
		31-Dec-14									31-Dec-13
		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	$	—		$	—		$	—		$	48	$	—	$	48
	Commodity contracts:
	Over-the-counter	106			—			106			4		—		4
	Exchange	—			—			—			1		—		1
	Total derivatives, subject to a master netting or similar arrangement	106			—			106			53		—		53
	Total derivatives, not subject to a master netting or similar arrangement	7			—			7			—		—		—
	Total	$	113		$	—		$	113		$	53	$	—	$	53
					31-Dec-14										31-Dec-13
					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	$	—		$	—		$	—		$	—	$	48	$	—	$	—	$	48
	Commodity contracts:
	Over-the-counter	106			4			—			102		4		4		—		—
	Exchange	—			—			—			—		1		—		—		1
	Total	$	106		$	4		$	—		$	102	$	53	$	4	$	—	$	49
Offsetting Liabilities
		31-Dec-14									31-Dec-13
		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	$	72		$	—		$	72		$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	8			—			8			12		—		12
	Total derivatives, subject to a master netting or similar arrangement	80			—			80			12		—		12
	Total derivatives, not subject to a master netting or similar arrangement	7			—			7			—		—		—
	Total	$	87		$	—		$	87		$	12	$	—	$	12
					31-Dec-14										31-Dec-13
					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	$	72		$	—		$	—		$	72	$	—	$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	8			4			—			4		12		4		7		1
	Total	$	80		$	4		$	—		$	76	$	12	$	4	$	7	$	1
Volumes of Derivatives	The following table presents the volume of Virginia Power's derivative activity at December 31, 2014. 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	7			—
	Basis	51			493
	Electricity (MWh):
	FTRs	33,709,386			—
	Capacity (MW)	10,700			7,600
	Interest rate	$	550,000,000		$	900,000,000
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following tables present the fair values of Virginia Power's derivatives and where they are presented in its Consolidated Balance Sheets:
		Fair Value  -			Fair Value -			Total
		Derivatives			Derivatives			Fair
		under			not under			Value
		Hedge			Hedge
		Accounting			Accounting
	(millions)
	At December 31, 2014
	ASSETS
	Current Assets
	Commodity	$	—		$	51		$	51
	Total current derivative assets(1)	—			51			51
	Noncurrent Assets
	Commodity	—			62			62
	Total noncurrent derivative assets(2)	—			62			62
	Total derivative assets	$	—		$	113		$	113
	LIABILITIES
	Current Liabilities
	Commodity	$	3		$	12		$	15
	Interest rate	45			—			45
	Total current derivative liabilities	48			12			60
	Noncurrent Liabilities
	Interest rate	27			—			27
	Total noncurrent derivative liabilities(3)	27			—			27
	Total derivative liabilities	$	75		$	12		$	87
	At December 31, 2013
	ASSETS
	Current Assets
	Commodity	$	2		$	3		$	5
	Interest rate	48			—			48
	Total current derivative assets(1)	50			3			53
	Total derivative assets	$	50		$	3		$	53
	LIABILITIES
	Current Liabilities
	Commodity	$	1		$	11		$	12
	Total current derivative liabilities	1			11			12
	Total derivative liabilities	$	1		$	11		$	12
	-1	Current derivative assets are presented in other current assets in Virginia Power's Consolidated Balance Sheets.
	-2	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power's Consolidated Balance Sheets.
	-3	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power's Consolidated Balance Sheets.
Derivative Instruments Gain (Loss) by Hedging Relationship by Income Statement Location	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	Amount of Gain			Amount of			Increase
	relationships	(Loss)			Gain (Loss)			(Decrease) in
		Recognized in			Reclassified			Derivatives
		AOCI on			from AOCI to			Subject to
		Derivatives			Income			Regulatory
		(Effective						Treatment(2)
		Portion)(1)
	(millions)
	Year Ended December 31, 2014
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	5
	Total commodity	$	4		$	5		$	(4	)
	Interest rate(3)	(10		)	—			(81		)
	Total	$	(6	)	$	5		$	(85	)
	Year Ended December 31, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	—
	Total commodity	$	—		$	—		$	5
	Interest rate(3)	9			—			81
	Total	$	9		$	—		$	86
	Year Ended December 31, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	(4	)
	Total commodity	$	(2	)	$	(4	)	$	10
	Interest rate(3)	(6		)	—			(35		)
	Total	$	(8	)	$	(4	)	$	(25	)
	-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
	Derivatives not designated as hedging	Amount of Gain (Loss) Recognized
	instruments	in Income on Derivatives(1)
	Year Ended December 31,	2014			2013			2012
	(millions)
	Derivative Type and Location of Gains (Losses)
	Commodity(2)	$	105		$	(16	)	$	(50	)
	Total	$	105		$	(16	)	$	(50	)
	-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.
Dominion Gas Holdings, LLC
Derivative [Line Items]
Offsetting Assets	The tables below present Dominion Gas' derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
		31-Dec-14									31-Dec-13
		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	$	—		$	—		$	—		$	34	$	—	$	34
	Commodity contracts:
	Over-the-counter	2			—			2			6		—		6
	Total derivatives, subject to a master netting or similar arrangement	$	2		$	—		$	2		$	40	$	—	$	40
					31-Dec-14										31-Dec-13
					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	$	—		$	—		$	—		$	—	$	34	$	—	$	—	$	34
	Commodity contracts:
	Over-the-counter	2			—			—			2		6		6		—		—
	Total	$	2		$	—		$	—		$	2	$	40	$	6	$	—	$	34
Offsetting Liabilities
		31-Dec-14									31-Dec-13
		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	$	9		$	—		$	9		$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	—			—			—			25		—		25
	Total derivatives, subject to a master netting or similar arrangement	$	9		$	—		$	9		$	25	$	—	$	25
					31-Dec-14										31-Dec-13
					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	$	9		$	—		$	—		$	9	$	—	$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	—			—			—			—		25		6		—		19
	Total	$	9		$	—		$	—		$	9	$	25	$	6	$	—	$	19
Volumes of Derivatives	The following table presents the volume of Dominion Gas' derivative activity at December 31, 2014. 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
	NGLs	32,340,000			—
	Interest rate	$	—		$	250,000,000
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 Gas' Consolidated Balance Sheet at December 31, 2014:
		AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum
		After-Tax						Term
	(millions)
	Commodities:
	Natural Gas	$	—		$	—		3 months
	NGLs	—			—			12 months
	Interest rate	(20		)	—			360 months
	Total	$	(20	)	$	—
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following tables present the fair values of Dominion Gas' derivatives and where they are presented in its Consolidated Balance Sheets:
		Fair Value  -			Fair Value -			Total
		Derivatives			Derivatives			Fair
		under			not under			Value
		Hedge			Hedge
		Accounting			Accounting
	(millions)
	At December 31, 2014
	ASSETS
	Current Assets
	Commodity	$	2		$	—		$	2
	Total current derivative assets(1)	2			—			2
	Total derivative assets	$	2		$	—		$	2
	LIABILITIES
	Noncurrent Liabilities
	Interest rate	$	9		$	—		$	9
	Total noncurrent derivative liabilities(2)	9			—			9
	Total derivative liabilities	$	9		$	—		$	9
	At December 31, 2013
	ASSETS
	Current Assets
	Commodity	$	6		$	—		$	6
	Interest rate	34			—			34
	Total current derivative assets(1)	40			—			40
	Total derivative assets	$	40		$	—		$	40
	LIABILITIES
	Current Liabilities
	Commodity	$	25		$	—		$	25
	Total current derivative liabilities(3)	25			—			25
	Total derivative liabilities	$	25		$	—		$	25
	-1	Current derivative assets are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.
	-2	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.
	-3	Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.
Derivative Instruments Gain (Loss) by Hedging Relationship by Income Statement Location	The following tables present the gains and losses on Dominion Gas' derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:
	Derivatives in cash flow hedging	Amount of Gain			Amount of
	relationships	(Loss)			Gain (Loss)
		Recognized in			Reclassified
		AOCI on			from AOCI to
		Derivatives			Income
		(Effective
		Portion)(1)
	(millions)
	Year Ended December 31, 2014
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	2
	Purchased gas				(14		)
	Total commodity	$	12		$	(12	)
	Interest rate(2)	(62		)	(1		)
	Total	$	(50	)	$	(13	)
	Year Ended December 31, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	(2	)
	Purchased gas				(14		)
	Total commodity	$	(2	)	$	(16	)
	Interest rate(2)	68			—
	Total	$	66		$	(16	)
	Year Ended December 31, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	(15	)
	Purchased gas				(18		)
	Total commodity	$	64		$	(33	)
	Interest rate(2)	(41		)	—
	Total	$	23		$	(33	)
	-1	Amounts deferred into AOCI have no associated effect in Dominion Gas' Consolidated Statements of Income.
	-2	Amounts recorded in Dominion Gas' Consolidated Statements of Income are classified in interest and related charges.

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share Computation	The following table presents the calculation of Dominion's basic and diluted EPS:
		2014		2013		2012
	(millions, except EPS)
	Net income attributable to Dominion	$	1,310	$	1,697	$	302
	Average shares of common stock outstanding-Basic	582.7		578.7		572.9
	Net effect of dilutive securities(1)	1.8		0.8		1
	Average shares of common stock outstanding-Diluted	584.5		579.5		573.9
	Earnings Per Common Share-Basic	$	2.25	$	2.93	$	0.53
	Earnings Per Common Share-Diluted	$	2.24	$	2.93	$	0.53
	-1	Dilutive securities consist primarily of contingently convertible senior notes and the 2013 Equity Units for 2014 and contingently convertible senior notes for 2013 and 2012. Dominion redeemed all of its contingently convertible senior notes in 2014. See Note 17 for more information.

Investments_Tables

Investments (Tables)	12 Months Ended
	Dec. 31, 2014
Schedule of Available-for-sale Securities [Line Items]
Available-For-Sale Securities	Dominion's decommissioning trust funds are summarized below:
		Amortized			Total			Total				Fair
		Cost			Unrealized			Unrealized				Value
					Gains (1)			Losses (1)
	(millions)
	2014
	Marketable equity securities:
	U.S. large cap	$	1,273		$	1,353		$	—			$	2,626
	Marketable debt securities:
	Corporate debt instruments	424			19			(2		)		441
	U.S. Treasury securities and agency debentures	597			13			(4		)		606
	State and municipal	332			23			—				355
	Other	66			—			—				66
	Cost method investments	86			—			—				86
	Cash equivalents and other(2)	16			—			—				16
	Total	$	2,794		$	1,408		$	(6	)	(3)	$	4,196
	2013
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,183		$	1,194		$	—			$	2,377
	Other	49			23			—				72
	Marketable debt securities:
	Corporate debt instruments	332			16			(3		)		345
	U.S. Treasury securities and agency debentures	589			8			(10		)		587
	State and municipal	297			11			(5		)		303
	Other	3			—			—				3
	Cost method investments	106			—			—				106
	Cash equivalents and other(2)	110			—			—				110
	Total	$	2,669		$	1,252		$	(18	)	(3)	$	3,903
	-1	Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
	-2	Includes pending sales of securities of $3 million and $11 million at December 31, 2014 and 2013, respectively.
	-3	The fair value of securities in an unrealized loss position was $379 million and $604 million at December 31, 2014 and 2013, respectively.
Investments Classified by Contractual Maturity Date	The fair value of Dominion's marketable debt securities held in nuclear decommissioning trust funds at December 31, 2014 by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	169
	Due after one year through five years	390
	Due after five years through ten years	426
	Due after ten years	483
	Total	$	1,468
Marketable Securities	Presented below is selected information regarding Dominion's marketable equity and debt securities held in nuclear decommissioning trust funds:
	Year Ended December 31,	2014			2013			2012
	(millions)
	Proceeds from sales	$	1,235		$	1,476		$	1,356
	Realized gains(1)	171			157			98
	Realized losses(1)	30			33			33
	-1	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Other Than Temporary Impairment Losses On Investment Securities	Dominion recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows:
	Year Ended December 31,	2014			2013			2012
	(millions)
	Total other-than-temporary impairment losses(1)	$	21		$	31		$	26
	Losses recorded to decommissioning trust regulatory liability	(5		)	(13		)	(10		)
	Losses recognized in other comprehensive income (before taxes)	(3		)	(10		)	(2		)
	Net impairment losses recognized in earnings	$	13		$	8		$	14
	-1	Amounts include other-than-temporary impairment losses for debt securities of $3 million, $18 million and $4 million at December 31, 2014, 2013 and 2012, respectively.
Investments Accounts Under Equity Method of Accounting	Investments that Dominion and Dominion Gas account for under the equity method of accounting are as follows:
	Company	Ownership%		Investment Balance						Description
	As of December 31,			2014			2013
	(millions)
	Dominion
	Blue Racer Midstream, LLC	50	%	$	671		$	510		Midstream gas and related services
	Fowler I Holdings LLC	50	%	134			149			Wind-powered merchant generation facility
	NedPower Mount Storm LLC	50	%	128			131			Wind-powered merchant generation facility
	Iroquois Gas Transmission System, LP	24.72	%	107			105			Gas transmission system
	Other(1)	various		41			21
	Total			$	1,081		$	916
	Dominion Gas
	Iroquois Gas Transmission System, LP	24.72	%	$	107		$	105		Gas transmission system
	Total			$	107		$	105
	(1) Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018. Includes Dominion's investment in Atlantic Coast Pipeline. See Note 15 for more information.
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Available-For-Sale Securities	Virginia Power's decommissioning trust funds are summarized below:
		Amortized			Total			Total				Fair
		Cost			Unrealized			Unrealized				Value
					Gains (1)			Losses (1)
	(millions)
	2014
	Marketable equity securities:
	U.S. large cap	$	563		$	594		$	—			$	1,157
	Marketable debt securities:
	Corporate debt instruments	242			9			(1		)		250
	U.S. Treasury securities and agency debentures	197			3			(2		)		198
	State and municipal	197			13			—				210
	Other	23			—			—				23
	Cost method investments	86			—			—				86
	Cash equivalents and other(2)	6			—			—				6
	Total	$	1,314		$	619		$	(3	)	(3)	$	1,930
	2013
	Marketable equity securities:
	U.S.:
	Large Cap	$	506		$	514		$	—			$	1,020
	Other	25			11			—				36
	Marketable debt securities:
	Corporate debt instruments	185			8			(2		)		191
	U.S. Treasury securities and agency debentures	214			1			(3		)		212
	State and municipal	163			4			(4		)		163
	Cost method investments	106			—			—				106
	Cash equivalents and other(2)	37			—			—				37
	Total	$	1,236		$	538		$	(9	)	(3)	$	1,765
	-1	Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
	-2	Includes pending sales of securities of $6 million at December 31, 2014 and 2013.
	-3	The fair value of securities in an unrealized loss position was $170 million and $299 million at December 31, 2014 and 2013, respectively.
Investments Classified by Contractual Maturity Date	The fair value of Virginia Power's marketable debt securities at December 31, 2014, by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	40
	Due after one year through five years	180
	Due after five years through ten years	242
	Due after ten years	219
	Total	$	681
Marketable Securities	Presented below is selected information regarding Virginia Power's marketable equity and debt securities.
	Year Ended December 31,	2014			2013			2012
	(millions)
	Proceeds from sales	$	549		$	572		$	626
	Realized gains(1)	73			52			42
	Realized losses(1)	12			14			11
	-1	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Other Than Temporary Impairment Losses On Investment Securities	Virginia Power recorded other-than-temporary impairment losses on investments as follows:
	Year Ended December 31,	2014			2013			2012
	(millions)
	Total other-than-temporary impairment losses(1)	$	8		$	15		$	11
	Losses recorded to decommissioning trust regulatory liability	(4		)	(13		)	(10		)
	Losses recorded in other comprehensive income (before taxes)	(2		)	(1		)	—
	Net impairment losses recognized in earnings	$	2		$	1		$	1
	-1	Amounts include other-than-temporary impairment losses for debt securities of $2 million, $9 million and $2 million at December 31, 2014, 2013 and 2012, respectively.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment, Net [Abstract]
Property, Plant and Equipment	Major classes of property, plant and equipment and their respective balances for the Companies are as follows:
	At December 31,	2014			2013
	(millions)
	Dominion
	Utility:
	Generation	$	15,193		$	14,018
	Transmission	9,897			8,686
	Distribution	12,354			11,714
	Storage	2,350			2,190
	Nuclear fuel	1,411			1,375
	Gas gathering and processing	791			787
	General and other	845			812
	Other-including plant under construction	3,633			3,261
	Total utility	46,474			42,843
	Nonutility:
	Merchant generation-nuclear	1,267			1,153
	Merchant generation-other	2,023			1,328
	Nuclear fuel	860			770
	Other-including plant under construction	782			875
	Total nonutility	4,932			4,126
	Total property, plant and equipment	$	51,406		$	46,969
	Virginia Power
	Utility:
	Generation	$	15,193		$	14,018
	Transmission	5,884			4,959
	Distribution	9,526			9,103
	Nuclear fuel	1,411			1,375
	General and other	697			668
	Other-including plant under construction	2,464			2,719
	Total utility	35,175			32,842
	Nonutility-other	5			6
	Total property, plant and equipment	$	35,180		$	32,848
	Dominion Gas
	Utility:
	Transmission	$	3,690		$	3,407
	Distribution	2,530			2,333
	Storage	1,466			1,314
	Gas gathering and processing	786			783
	General and other	111			103
	Plant under construction	179			175
	Total utility	8,762			8,115
	Nonutility:
	E&P properties being amortized and other	140			125
	Total nonutility	140			125
	Total property, plant and equipment	$	8,902		$	8,240
Share of Jointly-Owned Power Stations	Dominion's and Virginia Power's proportionate share of jointly-owned power stations at December 31, 2014 is as follows:
		Bath			North			Clover			Millstone
		County			Anna Units 1 and 2(1)			Power			Unit 3(2)
		Pumped						Station(1)
		Storage
		Station(1)
	(millions, except percentages)
	Ownership interest	60		%	88.4		%	50		%	93.5		%
	Plant in service	$	1,039		$	2,426		$	573		$	1,104
	Accumulated depreciation	(542		)	(1,137		)	(206		)	(290		)
	Nuclear fuel	—			627			—			480
	Accumulated amortization of nuclear fuel	—			(486		)	—			(342		)
	Plant under construction	11			114			11			71
	-1	Units jointly owned by Virginia Power.
	-2	Unit jointly owned by Dominion.

Recovered_Sheet1

Goodwill And Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Segment allocation of goodwill	The changes in Dominion's and Dominion Gas' carrying amount and segment allocation of goodwill are presented below:
		Dominion				Dominion				DVP			Corporate and		Total
		Generation				Energy							Other(1)
	(millions)
	Dominion
	Balance at December 31, 2012(2)	$	1,503			$	701			$	926		$	—	$	3,130
	Asset disposition adjustment	(19		)	(3)	(25		)	(4)	—			—		(44		)
	Balance at December 31, 2013(2)	$	1,484			$	676			$	926		$	—	$	3,086
	Asset disposition adjustment	(32		)	(3)	(10		)	(4)	—			—		(42		)
	Balance at December 31, 2014(2)	$	1,452			$	666			$	926		$	—	$	3,044
	Dominion Gas
	Balance at December 31, 2012(2)	$	—			$	552			$	—		$	—	$	552
	Asset disposition adjustment	—				(7		)	(4)	—			—		(7		)
	Balance at December 31, 2013(2)	$	—			$	545			$	—		$	—	$	545
	Asset disposition adjustment	—				(3		)	(4)	—			—		(3		)
	Balance at December 31, 2014(2)	$	—			$	542			$	—		$	—	$	542
	-1	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.
	-2	Goodwill amounts do not contain any accumulated impairment losses.
	-3	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
	-4	Related to assets sold or contributed to an affiliate or Blue Racer.
Components of intangible assets	The components of intangible assets are as follows:
	At December 31,	2014						2013
		Gross			Accumulated			Gross			Accumulated
		Carrying			Amortization			Carrying			Amortization
		Amount						Amount
	(millions)
	Dominion
	Software, licenses and other	$	877		$	312		$	867		$	308
	Emissions allowances	10			5			3			2
	Total	$	887		$	317		$	870		$	310
	Virginia Power
	Software, licenses and other	$	286		$	81		$	271		$	78
	Total	$	286		$	81		$	271		$	78
	Dominion Gas
	Software, licenses and other	$	192		$	113		$	180		$	98
	Total	$	192		$	113		$	180		$	98
Annual amortization expense of intangible assets	Annual amortization expense for these intangible assets is estimated to be as follows:
		2015			2016			2017			2018		2019
	(millions)
	Dominion	$	72		$	67		$	58		$	45	$	36
	Virginia Power	$	21		$	18		$	15		$	12	$	8
	Dominion Gas	$	17		$	16		$	13		$	11	$	11

Regulatory_Assets_and_Liabilit1

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets and Liabilities	Regulatory assets and liabilities include the following:
	At December 31,	2014		2013
	(millions)
	Dominion
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	124	$	89
	Deferred cost of fuel used in electric generation(2)	79		—
	Deferred nuclear refueling outage costs(3)	44		—
	Unrecovered gas costs(4)	36		50
	Other	64		78
	Regulatory assets-current	347		217
	Unrecognized pension and other postretirement benefit costs(5)	1,050		706
	Deferred rate adjustment clause costs(1)	250		287
	Income taxes recoverable through future rates(6)	133		155
	Derivatives(7)	101		16
	Other	108		64
	Regulatory assets-non-current	1,642		1,228
	Total regulatory assets	$	1,989	$	1,445
	Regulatory liabilities:
	PIPP(8)	$	71	$	76
	Other	99		52
	Regulatory liabilities-current(9)	170		128
	Provision for future cost of removal and AROs(10)	1,072		1,028
	Nuclear decommissioning trust(11)	815		693
	Deferred cost of fuel used in electric generation(2)	6		90
	Other	98		190
	Regulatory liabilities-non-current	1,991		2,001
	Total regulatory liabilities	$	2,161	$	2,129
	Virginia Power
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	117	$	62
	Deferred cost of fuel used in electric generation(2)	79		—
	Deferred nuclear refueling outage costs(3)	44		—
	Other	58		66
	Regulatory assets-current	298		128
	Deferred rate adjustment clause costs(1)	179		227
	Derivatives(7)	101		16
	Income taxes recoverable through future rates(6)	100		124
	Other	59		50
	Regulatory assets-non-current	439		417
	Total regulatory assets	$	737	$	545
	Regulatory liabilities:
	Other	$	90	$	41
	Regulatory liabilities-current	90		41
	Provision for future cost of removal(10)	852		807
	Nuclear decommissioning trust(11)	815		693
	Deferred cost of fuel used in electric generation(2)	6		90
	Other	10		7
	Regulatory liabilities-non-current	1,683		1,597
	Total regulatory liabilities	$	1,773	$	1,638
	Dominion Gas
	Regulatory assets:
	Unrecovered gas costs(4)	$	29	$	40
	Deferred rate adjustment clause costs(1)	7		27
	UEX Rider(12)	—		11
	Other	2		1
	Regulatory assets-current	38		79
	Unrecognized pension and other postretirement benefit costs(5)	242		194
	Deferred rate adjustment clause costs(1)	71		59
	Income taxes recoverable through future rates(6)	24		24
	Other	42		8
	Regulatory assets-non-current	379		285
	Total regulatory assets	$	417	$	364
	Regulatory liabilities:
PIPP(8)	$	71	$	76
Other	4		3
Regulatory liabilities-current	75		79
Provision for future cost of removal and AROs(10)	172		177
Unrecognized pension and other postretirement benefit costs(5)	—		18
Other	20		8
Regulatory liabilities-non-current	192		203
Total regulatory liabilities	$	267	$	282
-1	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects for Virginia Power. Reflects deferrals of costs associated with certain current and prospective rider projects for Dominion Gas. See Note 13 for more information.
-2	Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion's and Virginia Power’s generation operations. See Note 13 for more information. For 2014 and 2013, amount includes approximately $5 million related to DOE claims.
-3	Legislation enacted in Virginia in April 2014 requires Virginia Power to defer operation and maintenance costs incurred in connection with the refueling of any nuclear-powered generating plant. These deferred costs will be amortized over the refueling cycle, not to exceed 18 months.
-4	Reflects unrecovered gas costs at regulated gas operations, which are recovered through filings with the applicable regulatory authority.
-5	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.
-6	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.
-7	As discussed under Derivative Instruments in Note 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.
-8	Under PIPP, eligible customers can make reduced payments 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. See Note 13 for more information.
-9	Current regulatory liabilities are presented in other current liabilities in Dominion'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	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.
-12	Represents East Ohio’s deferrals for the UEX Rider which are recovered through rates which are filed annually. Most of East Ohio’s bad debt expense is recovered either through the UEX Rider or the PIPP Rider. See Note 13 for more information.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation [Abstract]
Changes to Asset Retirement Obligations	The changes to AROs during 2013 and 2014 were as follows:
		Amount
	(millions)
	Dominion
	AROs at December 31, 2012(1)	$	1,705
	Obligations incurred during the period	13
	Obligations settled during the period	(68		)
	Revisions in estimated cash flows(2)	(129		)
	Accretion	86
	Other	(29		)
	AROs at December 31, 2013(1)	$	1,578
	Obligations incurred during the period	40
	Obligations settled during the period	(82		)
	Revisions in estimated cash flows(3)	102
	Accretion	81
	Other	(5		)
	AROs at December 31, 2014(1)	$	1,714
	Virginia Power
	AROs at December 31, 2012	$	705
	Obligations incurred during the period	2
	Obligations settled during the period	(2		)
	Revisions in estimated cash flows(2)	(52		)
	Accretion	38
	Other	(2		)
	AROs at December 31, 2013	$	689
	Obligations incurred during the period	28
	Obligations settled during the period	(1		)
	Revisions in estimated cash flows(3)	108
	Accretion	37
	Other	(6		)
	AROs at December 31, 2014(4)	$	855
	Dominion Gas
	AROs at December 31, 2012	$	133
	Obligations incurred during the period	8
	Obligations settled during the period	(13		)
	Accretion	8
	Other	1
	AROs at December 31, 2013(5)(6)	$	137
	Obligations incurred during the period	2
	Obligations settled during the period	(8		)
	Accretion	8
	Other	8
	AROs at December 31, 2014(5)(6)	$	147
	-1	Includes $64 million, $94 million and $81 million reported in other current liabilities at December 31, 2012, 2013, and 2014, respectively.
	-2	Primarily reflects lower anticipated nuclear decommissioning costs.
	-3	Relates primarily to a shift of the delayed planned date on which the DOE is expected to begin accepting spent nuclear fuel.
	-4	Includes $7 million reported in other current liabilities at December 31, 2014.
	-5	Includes $2 million and $7 million reported in other current liabilities at December 31, 2013 and 2014, respectively.
	-6	Includes $135 million and $140 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2013 and 2014, respectively.

ShortTerm_Debt_And_Credit_Agre1

Short-Term Debt And Credit Agreements (Tables)	12 Months Ended
	Dec. 31, 2014
Short term Debt [Line Items]
Commercial paper bank loans and letters of credit outstanding as well as capacity available under credit facilities	Commercial paper and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:
		Facility		Outstanding			Outstanding		Facility
		Limit		Commercial			Letters of		Capacity
				Paper			Credit		Available
	(millions)
	At December 31, 2014
	Joint revolving credit facility(1)	$	4,000	$	2,664		$	—	$	1,336
	Joint revolving credit facility(2)	500		111			48		341
	Total	$	4,500	$	2,775	(3)	$	48	$	1,677
	At December 31, 2013
	Joint revolving credit facility(1)	$	3,000	$	1,927		$	—	$	1,073
	Joint revolving credit facility(2)	500		—			11		489
	Total	$	3,500	$	1,927	(3)	$	11	$	1,562
	-1	In May 2014, this credit facility was amended and restated. The facility limit was increased from $3 billion to $4 billion and the maturity date was extended from September 2018 to April 2019. 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	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by Dominion's credit facilities were 0.38% and 0.33% at December 31, 2014 and 2013, respectively.
Virginia Electric and Power Company
Short term Debt [Line Items]
Commercial paper bank loans and letters of credit outstanding as well as capacity available under credit facilities	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 and Dominion Gas were as follows:
		Facility Sub-limit		Outstanding Commercial Paper			Outstanding Letters of Credit		Facility Sub-limit Capacity Available
	(millions)
	At December 31, 2014
	Joint revolving credit facility(1)	$	1,250	$	1,250		$	—	$	—
	Joint revolving credit facility(2)	250		111			—		139
	Total	$	1,500	$	1,361	(3)	$	—	$	139
	At December 31, 2013
	Joint revolving credit facility(1)	$	1,000	$	842		$	—	$	158
	Joint revolving credit facility(2)	250		—			1		249
	Total	$	1,250	$	842	(3)	$	1	$	407
	-1	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. 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. In July 2014, Virginia Power increased its sub-limit from $1.0 billion to $1.25 billion. In January 2015, Virginia Power increased its sub-limit on this facility from $1.25 billion to $1.5 billion.
	-2	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. 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.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.36% and 0.33% at December 31, 2014 and 2013, respectively.

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Long-term Debt, Unclassified [Abstract]
Long term Debt
	At December 31,	2014 Weighted-		2014			2013
		average
		Coupon(1)
	(millions, except percentages)
	Dominion Gas Holdings, LLC:
	Unsecured Senior Notes:
	1.05% and 2.5%, due 2016 and 2019	1.82	%	$	850		$	400
	3.55% to 4.8%, due 2023 to 2044	4.15	%	1,750			800
	Dominion Gas Holdings, LLC total principal			$	2,600		$	1,200
	Unamortized discount			(6		)	(2		)
	Dominion Gas Holdings, LLC total long-term debt			$	2,594		$	1,198
	Virginia Electric and Power Company:
	Unsecured Senior Notes:
	1.2% to 8.625%, due 2015 to 2019	5.06	%	$	2,471		$	2,488
	2.75% to 8.875%, due 2022 to 2044	5.07	%	5,592			4,643
	Tax-Exempt Financings(2):
	Variable rates, due 2016 to 2041	0.93	%	606			606
	0.70% to 5.6%, due 2022 to 2040	2.86	%	266			306
	Virginia Electric and Power Company total principal			$	8,935		$	8,043
	Securities due within one year	5.39	%	(211		)	(58		)
	Unamortized discount and premium, net			2			(11		)
	Virginia Electric and Power Company total long-term debt			$	8,726		$	7,974
	Dominion Resources, Inc.:
	Unsecured Senior Notes:
	Variable rates, due 2014 and 2015	0.36	%	$	400		$	400
	1.25% to 8.875%, due 2014 to 2019	3.17	%	3,150			4,391
	2.75% to 7.0%, due 2021 to 2044(3)	4.93	%	4,449			3,499
	Unsecured Convertible Senior Notes, 2.125%, due 2023			—			43
	Tax-Exempt Financing, variable rate, due 2041	1.1	%	75			75
	Unsecured Junior Subordinated Notes Payable to Affiliated Trust, 8.4%, due 2031	8.4	%	10			10
	Enhanced Junior Subordinated Notes:
	5.75% to 8.375%, due 2054 to 2066	6.28	%	985			985
	Variable rate, due 2066	2.54	%	380			380
	Remarketable Subordinated Notes, 1.07% to 1.50%, due 2019 to 2021	1.3	%	2,100			1,100
	Unsecured Debentures and Senior Notes(4):
	5.0% due 2014			—			600
	6.8% and 6.875%, due 2026 and 2027	6.81	%	89			89
	Dominion Energy, Inc.:
	Tax-Exempt Financing, 2.375%, due 2033	2.38	%	27			27
	Dominion Gas Holdings, LLC total principal (from above)			2,600			1,200
	Virginia Electric and Power Company total principal (from above)			8,935			8,043
	Dominion Resources, Inc. total principal			$	23,200		$	20,842
	Fair value hedge valuation(5)			19			55
	Securities due within one year(6)	3.3	%	(1,375		)	(1,519		)
	Unamortized discount and premium, net			(39		)	(48		)
	Dominion Resources, Inc. total long-term debt			$	21,805		$	19,330
	-1	Represents weighted-average coupon rates for debt outstanding as of December 31, 2014.
	-2	These financings relate to certain pollution control equipment at Virginia Power's generating facilities. Certain variable rate tax-exempt financings are supported by a $120 million credit facility that terminates in April 2019.
	-3	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015. As a result, at December 31, 2014, the notes were included in Securities due within one year in the Consolidated Balance Sheets.
	-4	Represents debt assumed by Dominion from the merger of its former CNG subsidiary.
	-5	Represents the valuation of certain fair value hedges associated with Dominion's fixed rate debt.
	-6	Includes $4 million fair value hedge valuation in 2014 and $14 million of fair value hedge valuation in 2013.
Scheduled principal payments of long-term debt	Based on stated maturity dates rather than early redemption dates that could be elected by instrument holders, the scheduled principal payments of long-term debt at December 31, 2014, were as follows:
		2015			2016			2017			2018			2019			Thereafter			Total
	(millions, except percentages)
	Dominion Gas	$	—		$	400		$	—		$	—		$	450		$	1,750		$	2,600
	Weighted-average Coupon				1.05		%							2.5		%	4.15		%
	Virginia Power	$	211		$	476		$	679		$	850		$	350		$	6,369		$	8,935
	Weighted-average Coupon	5.39		%	5.24		%	5.43		%	4.17		%	5		%	4.64		%
	Dominion
	Unsecured Senior Notes(1)	$	861		$	1,308		$	1,354		$	1,350		$	2,000		$	11,878		$	18,751
	Tax-Exempt Financings	—			19			75			—			—			880			974
	Unsecured Junior Subordinated Notes Payable to Affiliated Trusts	—			—			—			—			—			10			10
	Enhanced Junior Subordinated Notes	—			—			—			—			—			1,365			1,365
	Remarketable Subordinated Notes	—			—			—			—			550			1,550			2,100
	Total	$	861		$	1,327		$	1,429		$	1,350		$	2,550		$	15,683		$	23,200
	Weighted-average Coupon	2.14		%	2.86		%	3.27		%	4.99		%	3.09		%	4.39		%
	-1	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015. As a result, at December 31, 2014, the notes were included in Securities due within one year in the Consolidated Balance Sheets.
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(1)			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	$	553.5		$	550		1.18	%	4.82	%	$	79.3		7/1/16	7/1/19
	7/1/14	20	$	982		$	1,000.00		1.5	%	4.875	%	$	142.8		7/1/17	7/1/20
	-1	Payments of $66 million and $17 million were made in 2014 and 2013, respectively. The stock purchase contract liability was $216 million and $139 million at December 31, 2014 and 2013, respectively.

Preferred_Stock_Tables

Preferred Stock (Tables)	12 Months Ended
	Dec. 31, 2014
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Schedule Of Preferred Stock	Presented below is a summary of the preferred stock redemptions:
	Dividend	Total Shares	Redemption Price Per Share
		(thousands)
	$5.00	107	$	112.5	(1)
	4.04	13	102.27		(1)
	4.2	15	102.5		(1)
	4.12	32	103.73		(1)
	4.8	73	101		(1)
	7.05	500	100		(1)
	6.98	600	100		(1)
	Flex Money Market Preferred 12/02, Series A	1,250	100		(2)
	Total	2,590
	-1	As part of Dominion's Liability Management Exercise, in September 2014, Virginia Power provided irrevocable notice to redeem all shares outstanding for each series of preferred stock. In October 2014, the stock was redeemed at the applicable price per share plus accumulated and unpaid dividends.
	-2	In February 2014, Virginia Power provided irrevocable notice to redeem the stock. In March 2014, the stock was redeemed at the applicable price per share plus accumulated and unpaid dividends at a rate reset in March 2011 of 6.12%. Dividends ceased accumulating on the stock upon payment of the redemption price, thus the rate was not reset in March 2014.

Equity_Tables

Equity (Tables)	12 Months Ended
	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated other comprehensive income (loss)	Presented in the table below is a summary of AOCI by component:
	At December 31,	2014			2013
	(millions)
	Dominion
	Net deferred losses on derivatives-hedging activities, net of tax of $116 and $196	$	(178	)	$	(288	)
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(333) and $(307)	548			474
	Net unrecognized pension and other postretirement benefit costs, net of tax of $530 and $365	(782		)	(510		)
	Other comprehensive loss from equity method investees, net of tax of $3 and $--	(4		)	—
	Total AOCI	$	(416	)	$	(324	)
	Virginia Power
	Net deferred losses on derivatives-hedging activities, net of tax of $4 and $---	$	(7	)	$	—
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(35) and $(30)	57			48
	Total AOCI	$	50		$	48
	Dominion Gas
	Net deferred gains (losses) on derivatives-hedging activities, net of tax of $11 and $(1)	$	(20	)	$	3
	Net unrecognized pension and other postretirement benefit costs, net of tax of $46 and $43	(66		)	(61		)
	Total AOCI	$	(86	)	$	(58	)
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			Other comprehensive loss from equity method investees			Total
	(millions)
	Year Ended December 31, 2014
	Beginning balance	$	(288	)	$	474		$	(510	)	$	—		$	(324	)
	Other comprehensive income before reclassifications: gains (losses)	17			128			(305		)	(4		)	(164		)
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	93			(54		)	33			—			72
	Net current period other comprehensive income (loss)	110			74			(272		)	(4		)	(92		)
	Ending balance	$	(178	)	$	548		$	(782	)	$	(4	)	$	(416	)
	Year Ended December 31, 2013
	Beginning balance	$	(122	)	$	326		$	(1,081	)	$	—		$	(877	)
	Other comprehensive income before reclassifications: gains (losses)	(243		)	203			516			—			476
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	77			(55		)	55			—			77
	Net current period other comprehensive income (loss)	(166		)	148			571			—			553
	Ending balance	$	(288	)	$	474		$	(510	)	$	—		$	(324	)
	(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)
	Year Ended December 31, 2014
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	130		Operating revenue
		13			Purchased gas
		(7		)	Electric fuel and other energy-related purchases
	Interest rate contracts	16			Interest and related charges
	Total	152
	Tax	(59		)	Income tax expense
	Total, net of tax	$	93
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(100	)	Other income
	Impairment	13			Other income
	Total	(87		)
	Tax	33			Income tax expense
	Total, net of tax	$	(54	)
	Unrecognized pension and other postretirement benefit costs:
	Prior-service costs (credits)	$	(12	)	Other operations and maintenance
	Actuarial losses	69			Other operations and maintenance
	Total	57
	Tax	(24		)	Income tax expense
	Total, net of tax	$	33
	Year Ended December 31, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	58		Operating revenue
		47			Purchased gas
		10			Electric fuel and other energy-related purchases
	Interest rate contracts	15			Interest and related charges
	Total	130
	Tax	(53		)	Income tax expense
	Total, net of tax	$	77
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(98	)	Other income
	Impairment	8			Other income
	Total	(90		)
	Tax	35			Income tax expense
	Total, net of tax	$	(55	)
	Unrecognized pension and other postretirement benefit costs:
	Prior-service costs (credits)	$	(8	)	Other operations and maintenance
	Actuarial losses	102			Other operations and maintenance
	Total	94
	Tax	(39		)	Income tax expense
	Total, net of tax	$	55
Summary of restricted stock activity	The following table provides a summary of restricted stock activity for the years ended December 31, 2014, 2013 and 2012:
		Shares		Weighted
				- average
				Grant Date
				Fair Value
		(thousands)
	Nonvested at December 31, 2011	1,301		$	37.37
	Granted	390		51.14
	Vested	(596	)	33.31
	Cancelled and forfeited	(10	)	42.99
	Nonvested at December 31, 2012	1,085		$	44.46
	Granted	312		54.7
	Vested	(356	)	39
	Cancelled and forfeited	(34	)	51.11
	Nonvested at December 31, 2013	1,007		$	49.35
	Granted	354		67.98
	Vested	(278	)	44.5
	Cancelled and forfeited	(18	)	53.61
	Nonvested at December 31, 2014	1,065		$	56.74
Summary of restricted stock and goal-based stock activity	The following table provides a summary of goal-based stock activity for the years ended December 31, 2014, 2013 and 2012:
		Targeted		Weighted
		Number of		- average
		Shares		Grant
				Date Fair
				Value
		(thousands)
	Nonvested at December 31, 2011	12		$	39.19
	Granted	1		52.48
	Vested	(9	)	37.46
	Nonvested at December 31, 2012	4		$	45.6
	Granted	4		54.17
	Vested	(2	)	43.54
	Cancelled and forfeited	(1	)	43.54
	Nonvested at December 31, 2013	5		$	53.85
	Granted	13		68.83
	Vested	(1	)	52.48
	Nonvested at December 31, 2014	17		$	65.15
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents Virginia Power’s changes in AOCI by component, net of tax:
		Deferred gains and losses on derivatives-hedging activities			Unrealized gains and losses on investment securities			Total
	(millions)
	Year Ended December 31, 2014
	Beginning balance	$	—		$	48		$	48
	Other comprehensive income before reclassifications: gains (losses)	(4		)	15			11
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	(3		)	(6		)	(9		)
	Net current period other comprehensive income (loss)	(7		)	9			2
	Ending balance	$	(7	)	$	57		$	50
	Year Ended December 31, 2013
	Beginning balance	$	(6	)	$	31		$	25
	Other comprehensive income before reclassifications: gains (losses)	6			20			26
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	—			(3		)	(3		)
	Net current period other comprehensive income (loss)	6			17			23
	Ending balance	$	—		$	48		$	48
	(1) See table below for details about these reclassifications.
Reclassification out of Accumulated Other Comprehensive Income	The following table presents Virginia Power’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)
	Year Ended December 31, 2014
	(Gains) losses on cash flow hedges:
	Commodity contracts	$	(5	)	Electric fuel and other energy-related purchases
	Interest rate contracts	—			Interest and related charges
	Total	(5		)
	Tax	2			Income tax expense
	Total, net of tax	$	(3	)
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(10	)	Other income
	Total	(10		)
	Tax	4			Income tax expense
	Total, net of tax	$	(6	)
	Year Ended December 31, 2013
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(6	)	Other income
	Impairment	1			Other income
	Total	(5		)
	Tax	2			Income tax expense
	Total, net of tax	$	(3	)
Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents Dominion Gas' changes in AOCI by component, net of tax:
		Deferred gains and losses on derivatives-hedging activities			Unrecognized pension and other postretirement benefit costs			Total
	(millions)
	Year Ended December 31, 2014
	Beginning balance	$	3		$	(61	)	$	(58	)
	Other comprehensive income before reclassifications: gains (losses)	(31		)	(10		)	(41		)
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	8			5			13
	Net current period other comprehensive income (loss)	(23		)	(5		)	(28		)
	Ending balance	$	(20	)	$	(66	)	$	(86	)
	Year Ended December 31, 2013
	Beginning balance	$	(47	)	$	(93	)	$	(140	)
	Other comprehensive income before reclassifications: gains (losses)	39			26			65
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	11			6			17
	Net current period other comprehensive income (loss)	50			32			82
	Ending balance	$	3		$	(61	)	$	(58	)
	(1) See table below for details about these reclassifications.
Reclassification out of Accumulated Other Comprehensive Income	The following table presents Dominion Gas' reclassifications out of AOCI by component:
	Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
	(millions)
	Year Ended December 31, 2014
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	(2	)	Operating revenue
		14			Purchased gas
		1			Interest and related charges
	Total	13
	Tax	(5		)	Income tax expense
	Total, net of tax	$	8
	Unrecognized pension and other postretirement benefit costs:
	Prior service costs	$	1		Other operations and maintenance
	Actuarial losses	7			Other operations and maintenance
	Total	8
	Tax	(3		)	Income tax expense
	Total, net of tax	$	5
	Year Ended December 31, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	2		Operating revenue
		14			Purchased gas
	Total	16
	Tax	(5		)	Income tax expense
	Total, net of tax	$	11
	Unrecognized pension and other postretirement benefit costs:
	Prior service costs	$	1		Other operations and maintenance
	Actuarial losses	9			Other operations and maintenance
	Total	10
	Tax	(4		)	Income tax expense
	Total, net of tax	$	6

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2014
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans funded status	The following table summarizes the changes in pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans' funded status for Dominion and Dominion Gas (for employees represented by collective bargaining units):
		Pension Benefits						Other Postretirement
								Benefits
	Year Ended December 31,	2014			2013			2014			2013
	(millions, except percentages)
	DOMINION
	Changes in benefit obligation:
	Benefit obligation at beginning of year	$	5,625		$	6,125		$	1,360		$	1,719
	Service cost	114			131			32			43
	Interest cost	290			271			67			73
	Benefits paid	(236		)	(229		)	(78		)	(75		)
	Actuarial (gains) losses during the year	887			(650		)	177			(170		)
	Plan amendments(1)	—			1			9			(220		)
	Settlements and curtailments(2)	(13		)	(24		)	—			(16		)
	Special termination benefits	—			—			—			1
	Medicare Part D reimbursement	—			—			4			5
	Benefit obligation at end of year	$	6,667		$	5,625		$	1,571		$	1,360
	Changes in fair value of plan assets:
	Fair value of plan assets at beginning of year	$	6,113		$	5,553		$	1,315		$	1,156
	Actual return on plan assets	601			781			105			178
	Employer contributions	15			8			12			12
	Benefits paid	(236		)	(229		)	(30		)	(31		)
	Settlements(2)	(13		)	—			—			—
	Fair value of plan assets at end of year	$	6,480		$	6,113		$	1,402		$	1,315
	Funded status at end of year	$	(187	)	$	488		$	(169	)	$	(45	)
	Amounts recognized in the Consolidated Balance Sheets at December 31:
	Noncurrent pension and other postretirement benefit assets	$	946		$	913		$	10		$	29
	Other current liabilities	(13		)	(15		)	(3		)	(3		)
	Noncurrent pension and other postretirement benefit liabilities	(1,120		)	(410		)	(176		)	(71		)
	Net amount recognized	$	(187	)	$	488		$	(169	)	$	(45	)
	Significant assumptions used to determine benefit obligations as of December 31:
	Discount rate(3)	4.4		%	5.20%/5.30%			4.4		%	5.00%/5.10%
	Weighted average rate of increase for compensation	4.22		%	4.21		%	4.22		%	4.22		%
	Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	7.75		%
	DOMINION GAS
	Changes in benefit obligation:
	Benefit obligation at beginning of year	$	563		$	607		$	269		$	287
	Service cost	12			13			6			7
	Interest cost	28			27			13			12
	Benefits paid	(29		)	(27		)	(16		)	(17		)
	Actuarial (gains) losses during the year	64			(57		)	38			(21		)
	Plan amendments	—			—			9			—
	Medicare Part D reimbursement	—			—			1			1
	Benefit obligation at end of year	$	638		$	563		$	320		$	269
	Changes in fair value of plan assets:
	Fair value of plan assets at beginning of year	$	1,403		$	1,254		$	273		$	242
	Actual return on plan assets	136			176			21			38
	Employer contributions	—			—			10			10
	Benefits paid	(29		)	(27		)	(16		)	(17		)
	Fair value of plan assets at end of year	$	1,510		$	1,403		$	288		$	273
	Funded status at end of year	$	872		$	840		$	(32	)	$	4
	Amounts recognized in the Consolidated Balance Sheets at December 31:
	Noncurrent pension and other postretirement benefit assets	$	872		$	840		$	—		$	19
	Noncurrent pension and other postretirement benefit liabilities(4)	—			—			(32		)	(15		)
	Net amount recognized	$	872		$	840		$	(32	)	$	4
	Significant assumptions used to determine benefit obligations as of December 31:
	Discount rate	4.4		%	5.2		%	4.4		%	5		%
	Weighted average rate of increase for compensation	3.93		%	3.93		%	3.93		%	3.93		%
	Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	7.75		%
	-1	2013 other postretirement benefits amount relates to a plan amendment that changed medical coverage for certain Medicare-eligible retirees.
	-2	2014 amounts relate primarily to a settlement charge for certain executives. 2013 amounts relate primarily to the decommissioning of Kewaunee.
	-3	2013 pension and other postretirement benefits discount rates: 5.20% and 5.00% for the gas union plans and 5.30% and 5.10% for the nonunion and other union plans, respectively.
	-4	Reflected in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.
Benefit obligation in excess of plan asset	The following table provides information on the benefit obligations and fair value of plan assets for plans with a benefit obligation in excess of plan assets for Dominion and Dominion Gas (for employees represented by collective bargaining units):
		Pension Benefits						Other Postretirement
								Benefits
	As of December 31,	2014			2013			2014			2013
	(millions)
	DOMINION
	Benefit obligation	$	5,970		$	4,978		$	1,564		$	1,233
	Fair value of plan assets	4,838			4,553			1,385			1,158
	DOMINION GAS
	Benefit obligation	$	—		$	—		$	320		$	147
	Fair value of plan assets	—			—			288			132
Accumulated benefit obligation in excess of plan assets	The following table provides information on the ABO and fair value of plan assets for Dominion’s pension plans with an ABO in excess of plan assets:
	As of December 31,	2014			2013
	(millions)
	Accumulated benefit obligation	$	5,370		$	114
	Fair value of plan assets	4,838			—
Benefit payments expected future service	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans:
		Estimated Future Benefit Payments
		Pension Benefits			Other  Postretirement Benefits
	(millions)
	DOMINION
	2015	$	272		$	91
	2016	284			94
	2017	300			98
	2018	320			101
	2019	333			102
	2020-2024	1,925			523
	DOMINON GAS
	2015	$	34		$	18
	2016	35			19
	2017	37			20
	2018	38			21
	2019	39			22
	2020-2024	204			111
Fair values of pension and post retirement plan assets by asset category	The fair values of Dominion's and Dominion Gas’ (for employees represented by collective bargaining units) pension plan assets by asset category are as follows:
		Fair Value Measurements
		Pension Plans
	At December 31,	2014												2013
		Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
	(millions)
	DOMINION
	Cash equivalents	$	13		$	25		$	—		$	38		$	53		$	126		$	—		$	179
	U.S. equity:
	Large Cap	1,313			—			—			1,313			1,220			—			—			1,220
	Other	530			—			—			530			514			—			—			514
	Non-U.S. equity:
	Large Cap	234			—			—			234			308			—			—			308
	Other	403			—			—			403			391			—			—			391
	Common/collective trust funds(1)	—			1,595			—			1,595			—			1,387			—			1,387
	Fixed income:
	Corporate debt instruments	45			666			—			711			43			451			—			494
	U.S. Treasury securities and agency debentures	74			342			—			416			2			229			—			231
	State and municipal	10			60			—			70			69			107			—			176
	Other securities	6			80			—			86			7			50			—			57
	Real estate:
	REITs	40			—			—			40			32			—			—			32
	Partnerships	—			—			209			209			—			—			227			227
	Other alternative investments:
	Private equity	—			—			518			518			—			—			530			530
	Debt	—			—			144			144			—			—			180			180
	Hedge funds	—			—			162			162			—			—			187			187
	Total(2)	$	2,668		$	2,768		$	1,033		$	6,469		$	2,639		$	2,350		$	1,124		$	6,113
	DOMINION GAS
	Cash equivalents	$	3		$	6		$	—		$	9		$	12		$	29		$	—		$	41
	U.S. equity:
	Large Cap	306			—			—			306			280			—			—			280
	Other	124			—			—			124			118			—			—			118
	Non-U.S. equity:
	Large Cap	54			—			—			54			72			—			—			72
	Other	94			—			—			94			90			—			—			90
	Common/collective trust funds(3)	—			372			—			372			—			318			—			318
	Fixed income:
	Corporate debt instruments	11			155			—			166			10			103			—			113
	U.S. Treasury securities and agency debentures	17			80			—			97			1			52			—			53
	State and municipal	2			14			—			16			16			24			—			40
	Other securities	1			19			—			20			2			11			—			13
	Real estate:
	REITs	9			—			—			9			7			—			—			7
	Partnerships	—			—			48			48			—			—			52			52
	Other alternative investments:
	Private equity	—			—			121			121			—			—			122			122
	Debt	—			—			34			34			—			—			41			41
	Hedge funds	—			—			38			38			—			—			43			43
	Total(4)	$	621		$	646		$	241		$	1,508		$	608		$	537		$	258		$	1,403
	-1	Common/Collective Trust Funds include $360 million and $560 million of John Hancock insurance contracts held at December 31, 2014 and 2013, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
	-2	Includes net assets related to pending sales of securities of $31 million, net accrued income of $18 million, and excludes net assets related to pending purchases of securities of $38 million at December 31, 2014.
	-3	See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
	-4	Includes net assets related to pending sales of securities of $7 million, net accrued income of $4 million, and excludes net assets related to pending purchases of securities of $9 million at December 31, 2014.
	The fair values of Dominion's and Dominion Gas’ (for employees represented by collective bargaining units) other postretirement plan assets by asset category are as follows:
		Fair Value Measurements
		Other Postretirement Plans
	At December 31,	2014												2013
		Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
	(millions)
	DOMINION
	Cash equivalents	$	1		$	7		$	—		$	8		$	3		$	14		$	—		$	17
	U.S. equity:
	Large Cap	514			—			—			514			472			—			—			472
Other	28			—			—			28			26			—			—			26
Non-U.S. equity:
Large Cap	102			—			—			102			111			—			—			111
Other	21			—			—			21			20			—			—			20
Common/collective trust funds(1)	—			555			—			555			—			502			—			502
Fixed income:
Corporate debt instruments	3			35			—			38			2			23			—			25
U.S. Treasury securities and agency debentures	4			18			—			22			—			12			—			12
State and municipal	1			3			—			4			4			5			—			9
Other securities	—			4			—			4			—			3			—			3
Real estate:
REITs	2			—			—			2			2			—			—			2
Partnerships	—			—			19			19			—			—			19			19
Other alternative investments:
Private equity	—			—			58			58			—			—			60			60
Debt	—			—			18			18			—			—			27			27
Hedge funds	—			—			9			9			—			—			10			10
Total	$	676		$	622		$	104		$	1,402		$	640		$	559		$	116		$	1,315
DOMINION GAS
Cash equivalents	$	—		$	2		$	—		$	2		$	—		$	3		$	—		$	3
U.S. equity-Large Cap	113			—			—			113			104			—			—			104
Non-U.S. equity-Large Cap	26			—			—			26			26			—			—			26
Common/collective trust funds(2)	—			129			—			129			—			119			—			119
Real estate - partnerships	—			—			2			2			—			—			2			2
Other alternative investments:
Private equity	—			—			12			12			—			—			12			12
Debt	—			—			4			4			—			—			7			7
Total	$	139		$	131		$	18		$	288		$	130		$	122		$	21		$	273
(1) Common/Collective Trust Funds include $19 million and $29 million of John Hancock insurance contracts held at December 31, 2014 and 2013, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
-2	See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
Pension plan and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category	The following table presents the changes in pension and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category for Dominion and Dominion Gas (for employees represented by collective bargaining units):
		Fair Value Measurements using Significant Unobservable Inputs (Level 3)
		Pension Plans															Other Postretirement Plans
		Real Estate			Private Equity			Debt			Hedge Funds			Total			Real Estate			Private Equity			Debt			Hedge Funds			Total
	DOMINION
	Balance at December 31, 2011	$	304		$	448		$	243		$	290		$	1,285		$	24		$	63		$	36		$	14		$	137
	Actual return on plan assets:
	Relating to assets still held at the reporting date	21			46			17			21			105			1			3			4			1			9
	Relating to assets sold during the period	(8		)	(41		)	(11		)	(2		)	(62		)	—			(1		)	—			—			(1		)
	Purchases	35			79			15			—			129			2			6			1			—			9
	Sales	(31		)	(76		)	(72		)	(88		)	(267		)	(3		)	(13		)	(10		)	(4		)	(30		)
	Balance at December 31, 2012	$	321		$	456		$	192		$	221		$	1,190		$	24		$	58		$	31		$	11		$	124
	Actual return on plan assets:
	Relating to assets still held at the reporting date	15			98			32			21			166			(2		)	6			3			1			8
	Relating to assets sold during the period	(36		)	(48		)	(34		)	(4		)	(122		)	1			3			—			1			5
	Purchases	6			115			32			—			153			1			7			2			—			10
	Sales	(79		)	(91		)	(42		)	(51		)	(263		)	(5		)	(14		)	(9		)	(3		)	(31		)
	Balance at December 31, 2013	$	227		$	530		$	180		$	187		$	1,124		$	19		$	60		$	27		$	10		$	116
	Actual return on plan assets:
	Relating to assets still held at the reporting date	40			70			12			4			126			4			7			2			—			13
	Relating to assets sold during the period	(18		)	(67		)	(26		)	(4		)	(115		)	(1		)	(7		)	(3		)	—			(11		)
	Purchases	—			135			10			—			145			—			13			1			—			14
	Sales	(40		)	(150		)	(32		)	(25		)	(247		)	(3		)	(15		)	(9		)	(1		)	(28		)
	Balance at December 31, 2014	$	209		$	518		$	144		$	162		$	1,033		$	19		$	58		$	18		$	9		$	104
	DOMINION GAS
	Balance at December 31, 2011	$	68		$	99		$	54		$	64		$	285		$	3		$	15		$	10		$	—		$	28
	Actual return on plan assets:
	Relating to assets still held at the reporting date	6			12			4			4			26			—			(1		)	(1		)	—			(2		)
	Relating to assets sold during the period	(2		)	(9		)	(2		)	—			(13		)	—			2			1			—			3
	Purchases	7			17			3			—			27			—			1			—			—			1
	Sales	(7		)	(16		)	(16		)	(18		)	(57		)	—			(4		)	(2		)	—			(6		)
	Balance at December 31, 2012	$	72		$	103		$	43		$	50		$	268		$	3		$	13		$	8		$	—		$	24
	Actual return on plan assets:
	Relating to assets still held at the reporting date	4			24			7			5			40			(1		)	2			1			—			2
	Relating to assets sold during the period	(8		)	(10		)	(7		)	(1		)	(26		)	—			—			—			—			—
	Purchases	1			25			7			—			33			—			1			—			—			1
	Sales	(17		)	(20		)	(9		)	(11		)	(57		)	—			(4		)	(2		)	—			(6		)
	Balance at December 31, 2013	$	52		$	122		$	41		$	43		$	258		$	2		$	12		$	7		$	—		$	21
	Actual return on plan assets:
	Relating to assets still held at the reporting date	9			17			4			1			31			—			2			1			—			3
	Relating to assets sold during the period	(4		)	(15		)	(6		)	(1		)	(26		)	—			(1		)	(1		)	—			(2		)
	Purchases	—			30			2			—			32			—			2			—			—			2
	Sales	(9		)	(33		)	(7		)	(5		)	(54		)	—			(3		)	(3		)	—			(6		)
	Balance at December 31, 2014	$	48		$	121		$	34		$	38		$	241		$	2		$	12		$	4		$	—		$	18
Net periodic benefit (credit) cost and amounts recognized in other comprehensive income and regulatory assets and liabilities	The components of the provision for net periodic benefit (credit) cost and amounts recognized in other comprehensive income and regulatory assets and liabilities for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans are as follows:
		Pension Benefits									Other Postretirement Benefits
	Year Ended December 31,	2014			2013			2012			2014			2013			2012
	(millions, except percentages)
	DOMINION
	Service cost	$	114		$	131		$	116		$	32		$	43		$	44
	Interest cost	290			271			268			67			73			79
	Expected return on plan assets	(499		)	(462		)	(430		)	(111		)	(92		)	(79		)
	Amortization of prior service (credit) cost	3			3			3			(28		)	(15		)	(13		)
	Amortization of net actuarial loss	111			165			132			2			7			6
	Settlements and curtailments(1)	1			(2		)	—			—			(15		)	(4		)
	Special termination benefits	—			—			—			—			1			—
	Net periodic benefit (credit) cost	$	20		$	106		$	89		$	(38	)	$	2		$	33
	Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
	Current year net actuarial (gain) loss	$	784		$	(968	)	$	786		$	183		$	(255	)	$	139
	Prior service (credit) cost	—			1			—			9			(215		)	1
	Settlements and curtailments(1)	(1		)	(22		)	—			—			(7		)	(2		)
	Less amounts included in net periodic benefit cost:
	Amortization of net actuarial loss	(111		)	(165		)	(132		)	(2		)	(7		)	(6		)
	Amortization of prior service credit (cost)	(3		)	(3		)	(3		)	28			15			13
	Total recognized in other comprehensive income and regulatory assets and liabilities	$	669		$	(1,157	)	$	651		$	218		$	(469	)	$	145
	Significant assumptions used to determine periodic cost:
	Discount rate	5.20% - 5.30%			4.40% - 4.80%			5.5		%	4.20% - 5.10%			4.40% - 4.80%			5.5		%
	Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	8.5		%	7.75		%	7.75		%
	Weighted average rate of increase for compensation	4.21		%	4.21		%	4.21		%	4.22		%	4.22		%	4.22		%
	Healthcare cost trend rate(2)										7		%	7		%	7		%
	Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)(2)										5		%	4.6		%	4.6		%
	Year that the rate reaches the ultimate trend rate(2)(3)										2018			2062			2061
	DOMINION GAS
	Service cost	$	12		$	13		$	11		$	6		$	7		$	7
	Interest cost	28			27			28			13			12			14
	Expected return on plan assets	(115		)	(106		)	(96		)	(23		)	(19		)	(16		)
	Amortization of prior service (credit) cost	1			1			1			(1		)	(3		)	(4		)
	Amortization of net actuarial loss	19			26			26			—			2			1
	Net periodic benefit (credit) cost	$	(55	)	$	(39	)	$	(30	)	$	(5	)	$	(1	)	$	2
	Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
	Current year net actuarial (gain) loss	$	43		$	(127	)	$	35		$	40		$	(40	)	$	12
	Prior service cost	—			—			—			10			—			—
	Less amounts included in net periodic benefit cost:
	Amortization of net actuarial loss	(19		)	(26		)	(26		)	—			(2		)	(1		)
	Amortization of prior service credit (cost)	(1		)	(1		)	(1		)	1			3			4
	Total recognized in other comprehensive income and regulatory assets and liabilities	$	23		$	(154	)	$	8		$	51		$	(39	)	$	15
	Significant assumptions used to determine periodic cost:
	Discount rate	5.2		%	4.40% - 4.80%			5.5		%	4.20% - 5.00%			4.40% - 4.70%			5.5		%
	Expected long-term rate of return on plan assets	8.75		%	8.5		%	8.5		%	8.5		%	7.75		%	7.75		%
	Weighted average rate of increase for compensation	3.93		%	3.93		%	3.93		%	3.93		%	3.93		%	3.93		%
	Healthcare cost trend rate(2)										7		%	7		%	7		%
	Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)(2)										5		%	4.6		%	4.6		%
	Year that the rate reaches the ultimate trend rate(2)(3)										2018			2062			2061
	-1	2013 amounts relate primarily to the decommissioning of Kewaunee.
	-2	Assumptions used to determine net periodic cost for the following year.
	-3	The Society of Actuaries model used to determine healthcare cost trend rates was updated in 2014. The new model converges to the ultimate trend rate much more quickly than previous models.
Components of AOCI and regulatory assets and liabilities that have not been recognized as components of periodic benefit (credit) cost	The components of AOCI and regulatory assets and liabilities for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans that have not been recognized as components of net periodic benefit (credit) cost are as follows:
		Pension Benefits						Other Postretirement Benefits
	At December 31,	2014			2013			2014			2013
	(millions)
	DOMINION
	Net actuarial (gain) loss	$	2,382		$	1,709		$	139		$	(40	)
	Prior service (credit) cost	7			10			(233		)	(271		)
	Total(1)	$	2,389		$	1,719		$	(94	)	$	(311	)
	DOMINION GAS
	Net actuarial loss	$	303		$	279		$	43		$	3
	Prior service (credit) cost	1			2			7			(4		)
	Total(2)	$	304		$	281		$	50		$	(1	)
	-1	As of December 31, 2014, of the $2.4 billion and $(94) million related to pension benefits and other postretirement benefits, $1.4 billion and $(81) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2013, of the $1.7 billion and $(311) million related to pension benefits and other postretirement benefits, $1.0 billion and $(156) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.
	-2	As of December 31, 2014, of the $304 million related to pension benefits, $112 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $50 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. As of December 31, 2013, of the $281 million related to pension benefits, $104 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $(1) million related to other postretirement benefits is included entirely in regulatory assets and liabilities.
Components of AOCI and regulatory assets and liabilities that are expected to be amortized as components of periodic benefit cost in 2014	The following table provides the components of AOCI and regulatory assets and liabilities for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) plans as of December 31, 2014 that are expected to be amortized as components of net periodic benefit (credit) cost in 2015:
		Pension			Other
		Benefits			Postretirement
					Benefits
	(millions)
	DOMINION
	Net actuarial loss	$	160		$	6
	Prior service (credit) cost	2			(27		)
	DOMINION GAS
	Net actuarial loss	$	20		$	2
	Prior service cost	1			—
Effect of one percentage point change on benefit plans	A one percentage point change in assumed healthcare cost trend rates would have had the following effects for Dominion’s and Dominion Gas’ (for employees represented by collective bargaining units) other postretirement benefit plans:
		Other Postretirement Benefits
		One percentage point increase			One percentage point decrease
	(millions)
	DOMINION
	Effect on net periodic cost for 2015	$	26		$	(16	)
	Effect on other postretirement benefit obligation at December 31, 2014	186			(152		)
	DOMINION GAS
	Effect on net periodic cost for 2015	$	5		$	(4	)
	Effect on other postretirement benefit obligation at December 31, 2014	40			(30		)

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Loss Contingencies [Line Items]
Nuclear Insurance	The current levels of nuclear property insurance coverage for Dominion's and Virginia Power's nuclear units is as follows:
		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 $200 million.
Lease Commitments	Future minimum lease payments under noncancelable operating and capital leases that have initial or remaining lease terms in excess of one year as of December 31, 2014 are as follows:
		2015		2016		2017		2018		2019		Thereafter		Total
	(millions)
	Dominion	$	63	$	57	$	49	$	43	$	36	$	79	$	327
	Virginia Power	$	30	$	26	$	21	$	18	$	12	$	26	$	133
	Dominion Gas	$	28	$	25	$	23	$	21	$	19	$	25	$	141
Subsidiary guarantees	At December 31, 2014, Dominion had issued the following subsidiary guarantees:
		Stated Limit		Value(1)
	(millions)
	Subsidiary debt(2)	$	27	$	27
	Commodity transactions(3)	3,151		919
	Nuclear obligations(4)	215		76
	Cove Point(5)	1,910		—
	Solar(6)	531		396
	Other(7)	532		35
	Total	$	6,366	$	1,453
	-1	Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2014 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 commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power, Dominion Gas 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 (in the event of a prolonged outage) and Kewaunee, respectively, 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, in support of terminal services, transportation and construction. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million.
	-6	Includes guarantees to facilitate the development of solar projects including guarantees to support the issuance of full notice to proceed under EPC agreements. Includes certain guarantees that do not have stated limits. Also includes guarantees entered into by DEI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects.
	-7	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. As of December 31, 2014, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $72 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million. The value provided includes certain guarantees that do not have stated limits.
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Long-term Purchase Commitment	At December 31, 2014, Virginia Power had the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that third parties have used to secure financing for the facilities that will provide the contracted goods or services:
		2015		2016		2017		2018		2019		Thereafter		Total
	(millions)
	Purchased electric capacity(1)	$	313	$	250	$	158	$	104	$	65	$	99	$	989
	-1	Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities and independent power producers, the last of which ends in 2021. Capacity payments under the contracts are generally based on fixed dollar amounts per month, subject to escalation using broad-based economic indices. At December 31, 2014, the present value of Virginia Power's total commitment for capacity payments is $833 million. Capacity payments totaled $330 million, $345 million, and $337 million, and energy payments totaled $304 million, $236 million, and $214 million for the years ended 2014, 2013 and 2012, respectively.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Schedules Of Transactions With Affiliates	Presented below are significant transactions with DRS and other affiliates:
	Year Ended December 31,	2014		2013		2012
	(millions)
	Commodity purchases from affiliates	$	543	$	417	$	368
	Services provided by affiliates(1)	432		415		399
	Services provided to affiliates	22		21		19
	(1) Includes capitalized expenditures.
Dominion Gas Holdings, LLC
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	Dominion Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Gas provides transportation and storage services to affiliates. Dominion Gas also enters into certain other contracts with affiliates, which are presented separately from contracts involving commodities or services. As of December 31, 2014 and 2013, all of Dominion Gas' commodity derivatives were with affiliates. See Notes 7 and 19 for more information. See Note 9 for information regarding sales of assets to an affiliate.
	Dominion Gas participates in certain Dominion benefit plans as described in Note 21. At December 31, 2014 and 2013, Dominion Gas' amounts due from Dominion associated with the Dominion Pension Plan and reflected in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets, were $614 million and $577 million, respectively. At December 31, 2014 and 2013, Dominion Gas' liabilities to Dominion associated with the Dominion Retiree Health and Welfare Plan and reflected in other deferred credits and other liabilities in the Consolidated Balance Sheets were $7 million and $14 million, respectively.
	Year Ended December 31,	2014		2013		2012
	(millions)
	Purchases of natural gas and transportation and storage services from affiliates	$	34	$	31	$	14
	Sales of natural gas and transportation and storage services to affiliates	84		109		64
	DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to affiliates, including technical services. The costs of these services follow:
	Year Ended December 31,	2014		2013		2012
	(millions)
	Services provided by affiliates(1)	$	106	$	116	$	107
	Services provided to affiliates	17		4		3
	(1) Includes capitalized expenditures.
	The following table presents affiliated and related party activity reflected in Dominion Gas' Consolidated Balance Sheets:
		December 31,
		2014		2013
	(millions)
	Customer receivables from related parties(1)	$	22	$	3
	Imbalances receivable from affiliates(2)	3		6
	Imbalances payable to affiliates(3)	—		1
	Affiliated notes receivable(4)	9		5
	-1	Includes $17 million due from Atlantic Coast Pipeline, an affiliated VIE.
	-2	Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.
	(3) Amounts are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.
	(4) Amounts are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.

Operating_Segments_Tables

Operating Segments (Tables)	12 Months Ended
	Dec. 31, 2014
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	Description of Operations	Dominion	Virginia	Dominion Gas
	Segment			Power
	DVP	Regulated electric distribution	X	X
		Regulated electric transmission	X	X
	Dominion Generation	Regulated electric fleet	X	X
		Merchant electric fleet	X
		Nonregulated retail energy marketing	X
	Dominion Energy	Gas transmission and storage(1)	X		X
		Gas distribution and storage	X		X
		Gas gathering and processing	X		X
		LNG import and storage	X
	(1) Includes remaining producer services activities.
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion's operations:
	Year Ended December 31,	DVP			Dominion			Dominion			Corporate and			Adjustments &			Consolidated
					Generation			Energy			Other			Eliminations			Total
	(millions)
	2014
	Total revenue from external customers	$	1,918		$	7,665		$	1,718		$	(12	)	$	1,147		$	12,436
	Intersegment revenue	18			70			1,174			572			(1,834		)	—
	Total operating revenue	1,936			7,735			2,892			560			(687		)	12,436
	Depreciation, depletion and amortization	462			516			241			73			—			1,292
	Equity in earnings of equity method investees	—			(18		)	54			10			—			46
	Interest income	—			67			14			20			(33		)	68
	Interest and related charges	205			240			11			770			(33		)	1,193
	Income taxes	317			392			436			(693		)	—			452
	Net income (loss) attributable to Dominion	502			1,101			677			(970		)	—			1,310
	Investment in equity method investees	—			262			796			23			—			1,081
	Capital expenditures	1,652			2,466			1,329			104			—			5,551
	Total assets (billions)	13			24.2			12.7			8.7			(4.3		)	54.3
	2013
	Total revenue from external customers	$	1,825		$	8,445		$	1,783		$	3		$	1,064		$	13,120
	Intersegment revenue	9			68			1,063			609			(1,749		)	—
	Total operating revenue	1,834			8,513			2,846			612			(685		)	13,120
	Depreciation, depletion and amortization	427			518			228			35			—			1,208
	Equity in earnings of equity method investees	—			(14		)	21			7			—			14
	Interest income	—			66			12			42			(66		)	54
	Interest and related charges	175			220			26			522			(66		)	877
	Income taxes	287			483			409			(287		)	—			892
	Loss from discontinued operations, net of tax	—			—			—			(92		)	—			(92		)
	Net income (loss) attributable to Dominion	475			1,031			643			(452		)	—			1,697
	Investment in equity method investees	—			280			615			21			—			916
	Capital expenditures	1,361			1,605			1,043			95			—			4,104
	Total assets (billions)	11.9			22			12.1			8.5			(4.4		)	50.1
	2012
	Total revenue from external customers	$	1,846		$	8,170		$	1,813		$	155		$	851		$	12,835
	Intersegment revenue	9			104			930			608			(1,651		)	—
	Total operating revenue	1,855			8,274			2,743			763			(800		)	12,835
	Depreciation, depletion and amortization	392			483			216			36			—			1,127
	Equity in earnings of equity method investees	—			3			23			(1		)	—			25
	Interest income	1			65			30			71			(106		)	61
	Interest and related charges	187			177			47			511			(106		)	816
	Income taxes	278			576			352			(395		)	—			811
	Loss from discontinued operations, net of tax	—			—			—			(1,125		)	—			(1,125		)
	Net income (loss) attributable to Dominion	439			1,021			551			(1,709		)	—			302
	Capital expenditures	1,158			1,615			1,350			22			—			4,145
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:
	Year Ended December 31,	DVP			Dominion			Corporate and			Adjustments &			Consolidated
					Generation			Other			Eliminations			Total
	(millions)
	2014
	Operating revenue	$	1,928		$	5,651		$	—		$	—		$	7,579
	Depreciation and amortization	462			416			37			—			915
	Interest income	—			8			—			—			8
	Interest and related charges	205			203			3			—			411
	Income taxes	317			416			(185		)	—			548
	Net income (loss)	509			691			(342		)	—			858
	Capital expenditures	1,651			1,456			—			—			3,107
	Total assets (billions)	13.2			16.4			—			(0.1		)	29.5
	2013
	Operating revenue	$	1,826		$	5,475		$	(6	)	$	—		$	7,295
	Depreciation and amortization	427			425			1			—			853
	Interest income	—			6			—			—			6
	Interest and related charges	175			192			2			—			369
	Income taxes	286			399			(26		)	—			659
	Net income (loss)	483			702			(47		)	—			1,138
	Capital expenditures	1,360			1,173			—			—			2,533
	Total assets (billions)	12			15.1			—			(0.1		)	27
	2012
	Operating revenue	$	1,847		$	5,379		$	—		$	—		$	7,226
	Depreciation and amortization	392			390			—			—			782
	Interest income	1			7			—			—			8
	Interest and related charges	186			199			—			—			385
	Income taxes	277			403			(27		)	—			653
	Net income (loss)	448			653			(51		)	—			1,050
	Capital expenditures	1,142			1,146			—			—			2,288
Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion Gas' operations:
	Year Ended December 31,	Dominion Energy			Corporate and			Consolidated
					Other			Total
	(millions)
	2014
	Operating revenue	$	1,898		$	—		$	1,898
	Depreciation and amortization	197			—			197
	Equity in earnings of equity method investees	21			—			21
	Interest income	1			—			1
	Interest and related charges	27			—			27
	Income taxes	340			(6		)	334
	Net income (loss)	521			(9		)	512
	Investment in equity method investees	107			—			107
	Capital expenditures	719			—			719
	Total assets (billions)	9.2			0.6			9.8
	2013
	Operating revenue	$	1,937		$	—		$	1,937
	Depreciation and amortization	188			—			188
	Equity in earnings of equity method investees	22			—			22
	Interest income	2			—			2
	Interest and related charges	28			—			28
	Income taxes	333			(32		)	301
	Net income (loss)	510			(49		)	461
	Investment in equity method investees	105			—			105
	Capital expenditures	650			—			650
	Total assets (billions)	8.5			0.6			9.1
	2012
	Operating revenue	$	1,677		$	—		$	1,677
	Depreciation and amortization	176			—			176
	Equity in earnings of equity method investees	23			—			23
	Interest income	2			—			2
	Interest and related charges	40			—			40
	Income taxes	293			(5		)	288
	Net income (loss)	469			(10		)	459
	Capital expenditures	928			—			928

Quarterly_Financial_and_Common1

Quarterly Financial and Common Stock Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Quarterly Financial and Common Stock Data
		First		Second			Third			Fourth		Year
		Quarter		Quarter			Quarter			Quarter
	(millions, except per share amounts)
	2014
	Operating revenue	$	3,630	$	2,813		$	3,050		$	2,943	$	12,436
	Income from operations	768		394			921			638		2,721
	Net income including noncontrolling interests	385		161			531			249		1,326
	Income from continuing operations(1)	379		159			529			243		1,310
	Net income attributable to Dominion	379		159			529			243		1,310
	Basic EPS:
	Income from continuing operations(1)	0.65		0.27			0.91			0.42		2.25
	Net income attributable to Dominion	0.65		0.27			0.91			0.42		2.25
	Diluted EPS:
	Income from continuing operations(1)	0.65		0.27			0.9			0.42		2.24
	Net income attributable to Dominion	0.65		0.27			0.9			0.42		2.24
	Dividends declared per share	0.6		0.6			0.6			0.6		2.4
	Common stock prices (intraday high-low)	$72.22  -		$73.75  -			$71.62 - 64.71			$80.89  -		$80.89  -
		63.14		67.06						65.53		63.14
	2013
	Operating revenue	$	3,523	$	2,980		$	3,432		$	3,185	$	13,120
	Income from operations	930		548			1,034			804		3,316
	Net income including noncontrolling interests	502		208			575			435		1,720
	Income from continuing operations(1)	494		272			592			431		1,789
	Income (loss) from discontinued operations(1)	1		(70		)	(23		)	—		(92		)
	Net income attributable to Dominion	495		202			569			431		1,697
	Basic EPS:
	Income from continuing operations(1)	0.86		0.47			1.02			0.74		3.09
	Income (loss) from discontinued operations(1)	—		(0.12		)	(0.04		)	—		(0.16		)
	Net income attributable to Dominion	0.86		0.35			0.98			0.74		2.93
	Diluted EPS:
	Income from continuing operations(1)	0.86		0.47			1.02			0.74		3.09
	Income (loss) from discontinued operations(1)	—		(0.12		)	(0.04		)	—		(0.16		)
	Net income attributable to Dominion	0.86		0.35			0.98			0.74		2.93
	Dividends declared per share	0.5625		0.5625			0.5625			0.5625		2.25
	Common stock prices (intraday high-low)	$58.25  -		$61.85  -			$64.04 - 55.51			$67.97  -		$67.97  -
		51.92		53.79						61.36		51.92
	-1	Amounts attributable to Dominion's common shareholders.
Virginia Electric and Power Company
Condensed Financial Statements, Captions [Line Items]
Quarterly Financial and Common Stock Data	Virginia Power's quarterly results of operations were as follows:
		First		Second			Third			Fourth		Year
		Quarter		Quarter			Quarter			Quarter
	(millions)
	2014
	Operating revenue	$	1,983	$	1,729		$	2,053		$	1,814	$	7,579
	Income from operations	613		205			594			312		1,724
	Net income	324		69			314			151		858
	Balance available for common stock	318		67			312			148		845
	2013
	Operating revenue	$	1,781	$	1,710		$	2,059		$	1,745	$	7,295
	Income from operations	530		463			679			408		2,080
	Net income	287		265			387			199		1,138
	Balance available for common stock	283		261			383			194		1,121
Dominion Gas Holdings, LLC
Condensed Financial Statements, Captions [Line Items]
Quarterly Financial and Common Stock Data	Dominion Gas' quarterly results of operations were as follows:
		First		Second			Third			Fourth		Year
		Quarter		Quarter			Quarter			Quarter
	(millions)
	2014
	Operating revenue	$	569	$	428		$	391		$	510	$	1,898
	Income from operations	265		154			177			255		851
	Net income	164		93			107			148		512
	2013
	Operating revenue	$	586	$	430		$	388		$	533	$	1,937
	Income from operations	224		88			217			233		762
	Net income	138		53			130			140		461

Nature_of_Operations_Narrative

Nature of Operations (Narrative) (Details) (USD $)	12 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Oct. 31, 2014
	Segment
Subsidiary, Sale of Stock [Line Items]
Number of operating segments	3
Dominion Midstream Partners, LP | IPO
Subsidiary, Sale of Stock [Line Items]
Common units included in initial public offering		20,125,000
Price per unit for units included in initial public offering		$21
Net proceeds received from sale of units		$392
Percentage of limited partner interests in Dominion Midstream Partners, LP		68.50%
Dominion Midstream Partners, LP | Over-Allotment Option
Subsidiary, Sale of Stock [Line Items]
Common units included in initial public offering		2,625,000
Virginia Electric and Power Company
Subsidiary, Sale of Stock [Line Items]
Number of operating segments	2
Dominion Gas Holdings, LLC
Subsidiary, Sale of Stock [Line Items]
Number of operating segments	1

Significant_Accounting_Policie3

Significant Accounting Policies (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Accounting Policy [Line Items]
Accrued unbilled revenue	$564	$555
Percentage of fuel currently subject to deferred fuel accounting	84.00%
Accounts payable for checks outstanding	42	38
Margin assets	287	620
Margin liabilities	34	2
Capitalized interest costs	80	66	91
Virginia Electric and Power Company
Accounting Policy [Line Items]
Accrued unbilled revenue	407	395
Income tax receivable	225
Noncurrent income tax payable	38	28
Income tax payable		22
Accounts payable for checks outstanding	20	21
Margin assets	6	11
Capitalized interest costs	39	33	31
AFUDC related to projects	8	32	37
Dominion Gas Holdings, LLC
Accounting Policy [Line Items]
Accrued unbilled revenue	127	106
Accounts payable for checks outstanding	9	7
Capitalized interest costs	1	5	23
Inventory under LIFO method	12	7
Amount exceeded on LIFO basis	98	77
State | Virginia Electric and Power Company
Accounting Policy [Line Items]
Income tax receivable		3
Noncurrent income taxes receivable	13	12
State | Dominion Gas Holdings, LLC
Accounting Policy [Line Items]
Noncurrent income taxes receivable	20	20
Noncurrent income tax payable	7	7
Income taxes payable	14	23
Income Taxes Receivable, Current		1
Federal | Dominion Gas Holdings, LLC
Accounting Policy [Line Items]
Income tax receivable	96
Income taxes payable		$17

Significant_Accounting_Policie4

Significant Accounting Policies (Depreciation Rates and Estimated Useful Life) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Increase in depreciation	38	19
Increase in depreciation, after tax	23	12
Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Decrease in depreciation		8
Decrease in depreciation, after tax		5
Generation
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.66%	2.71%	2.62%
Generation | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.66%	2.71%	2.62%
Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.38%	2.36%	2.17%
Transmission | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.34%	2.28%	1.98%
Transmission | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.40%	2.43%	2.35%
Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.12%	3.13%	3.17%
Distribution | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.34%	3.33%	3.32%
Distribution | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.47%	2.50%	2.66%
Storage
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.39%	2.43%	2.59%
Storage | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.40%	2.43%	2.58%
Gas gathering and processing
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.81%	2.39%	2.49%
Gas gathering and processing | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.82%	2.39%	2.50%
General and other
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.62%	3.82%	4.55%
General and other | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.29%	3.51%	4.32%
General and other | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	5.77%	5.93%	6.09%
Merchant generation-nuclear
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives	44 years
Minimum | General and other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives	5 years
Minimum | Merchant generation-other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives	15 years
Maximum | General and other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives	59 years
Maximum | Merchant generation-other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives	36 years

Acquisitions_and_Dispositions_1

Acquisitions and Dispositions (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended		6 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2014	Jun. 30, 2013	Jun. 30, 2013	Aug. 31, 2013	Nov. 30, 2014	Dec. 31, 2014	Sep. 30, 2014	Jan. 31, 2015
								MW	MW	MW	mi
										Project
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of electric retail energy marketing business	$187	$0	$0
Asset disposition adjustment	42	44
Impairment charge			1,600
Electric Retail Energy Marketing Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of electric retail energy marketing business				187
Gain on sale				100
After-tax gain on sale				57
Asset disposition adjustment				31
Illinois Gas Contracts
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale					29
After-tax gain on sale					18
Asset disposition adjustment					3
Sales price					32	32
Brayton Point and Kincaid
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment charge			1,600			48
Long-lived assets impairment charges, net of tax						28
Loss from discontinued operation		17
Loss on discontinued operation, net of tax		18
Loss from Discontinued Operations | Brayton Point and Kincaid
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Asset disposition adjustment		16
Elwood
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage							50.00%
Proceeds from sale of equity method investment							465
Elwood | Other Income
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of investment							35
After tax gain on sale of investment							25
Recurrent Energy Development Holdings, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired				100.00%
Number of solar development projects acquired				6
Purchase price				50
Estimated project cost once constructed				446
Generation capacity of solar development projects				139
CSI Project Holdco, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired								100.00%
Purchase price								79
Estimated project cost once constructed								80
Generation capacity of solar development projects								20
EDF Renewable Development, Inc.
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired	100.00%								100.00%	100.00%
Number of solar development projects acquired										2
Purchase price									71	175
Estimated project cost once constructed	73								73	185
Generation capacity of solar development projects									20	42
CGT | Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired											100.00%
Purchase price											$495
Length of FERC regulated interstate natural gas pipeline											1,500

Acquisitions_and_Dispositions_2

Acquisitions and Dispositions (Schedule of Disposal Groups, Including Discontinued Operations, Income Statement) (Details) (USD $)	6 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2013		Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment charge				$1,600
Brayton Point and Kincaid
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating revenue		304		258
Loss before income taxes		-135	[1]	-1,768	[2]
Charges related to early redemption of debt		64
Impairment charge	48			1,600
State Line and Salem Harbor
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating revenue				57
Loss before income taxes				($49)
[1]	Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013.
[2]	Includes a long-lived asset impairment charge of $1.6 billion.

Operating_Revenue_Operating_Re

Operating Revenue (Operating Revenue) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Electric sales:
Regulated									$7,460		$7,193		$7,102
Nonregulated									1,839		2,511		2,483
Gas sales:
Regulated									334		323		250
Nonregulated									751		930		1,071
Gas transportation and storage									1,543		1,535		1,401
Other									509		628		528
Total operating revenue	2,943	3,050	2,813	3,630	3,185	3,432	2,980	3,523	12,436		13,120		12,835
Virginia Electric and Power Company
Electric sales:
Regulated									7,460		7,193		7,102
Gas sales:
Other									119		102		124
Total operating revenue	1,814	2,053	1,729	1,983	1,745	2,059	1,710	1,781	7,579	[1]	7,295	[1]	7,226	[1]
Dominion Gas Holdings, LLC
Gas sales:
Regulated									209		202		138
Nonregulated									26		32		28
Gas transportation and storage									1,353		1,338		1,188
NGL revenue									212		292		275
Other									98		73		48
Total operating revenue	$510	$391	$428	$569	$533	$388	$430	$586	$1,898	[2]	$1,937	[2]	$1,677	[2]
[1]	See Note 24 for amounts attributable to affiliates.
[2]	See Note 24 for amounts attributable to related parties.

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2015
Operating Loss Carryforwards [Line Items]
Investment tax credits	($152)	($48)	$0
Unrecognized tax benefits that would impact effective tax rate	77	126	167
Change in unrecognized tax benefits	-47	-29	1
Decrease in Unrecognized tax benefits due to settlement negotiations and expiration of statutes of limitations	30
Scenario, Forecast
Operating Loss Carryforwards [Line Items]
Amount that earnings could potentially increase if changes were to occur				10
Federal
Operating Loss Carryforwards [Line Items]
Operating loss carryforward	2,200
Investment tax credits	245
Tax credits	65
Payment after conclusion of audit			46
State
Operating Loss Carryforwards [Line Items]
Operating loss carryforward	1,700
Carryforwards valuation allowance	962
General Business | State
Operating Loss Carryforwards [Line Items]
Tax credits	194
Investment Credit That Expires In 2014 | State
Operating Loss Carryforwards [Line Items]
Tax credits	29
Virginia Electric and Power Company
Operating Loss Carryforwards [Line Items]
Noncurrent income tax payable	38	28
Income tax receivable	225
Investment tax credits	0	0	0
Unrecognized tax benefits that would impact effective tax rate	8	8	13
Change in unrecognized tax benefits	1	4	1
Decrease in Unrecognized tax benefits due to settlement negotiations and expiration of statutes of limitations	25
Virginia Electric and Power Company | Scenario, Forecast
Operating Loss Carryforwards [Line Items]
Amount that earnings could potentially increase if changes were to occur				7
Virginia Electric and Power Company | Federal
Operating Loss Carryforwards [Line Items]
Operating loss carryforward	279
Tax credits	14
Virginia Electric and Power Company | State
Operating Loss Carryforwards [Line Items]
Income tax receivable		3
Dominion Gas Holdings, LLC
Operating Loss Carryforwards [Line Items]
Investment tax credits	0	0	0
Unrecognized tax benefits that would impact effective tax rate		19	20
Change in unrecognized tax benefits	1	1	1
Dominion Gas Holdings, LLC | Federal
Operating Loss Carryforwards [Line Items]
Income tax receivable	96
Operating loss carryforward	25
Dominion Gas Holdings, LLC | State
Operating Loss Carryforwards [Line Items]
Noncurrent income tax payable	7	7
Operating loss carryforward	$4

Income_Taxes_Income_Tax_Expens

Income Taxes (Income Tax Expense for Continuing Operations Including Noncontrolling Interests) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current:
Federal	($11)	$317	$43
State	14	110	84
Total current expense (benefit)	3	427	127
Federal
Taxes before operating loss carryforwards and investment tax credits	956	563	645
Tax benefit of operating loss carryforwards	-352	-18	0
Investment tax credits	-152	-48	0
State	-2	-31	40
Total deferred expense	450	466	685
Amortization of deferred investment tax credits	-1	-1	-1
Total income tax expense	452	892	811
Virginia Electric and Power Company
Current:
Federal	85	357	70
State	67	62	81
Total current expense (benefit)	152	419	151
Federal
Taxes before operating loss carryforwards and investment tax credits	381	224	482
Tax benefit of operating loss carryforwards	0	0	0
Investment tax credits	0	0	0
State	16	17	21
Total deferred expense	397	241	503
Amortization of deferred investment tax credits	-1	-1	-1
Total income tax expense	548	659	653
Dominion Gas Holdings, LLC
Current:
Federal	86	158	-8
State	32	41	2
Total current expense (benefit)	118	199	-6
Federal
Taxes before operating loss carryforwards and investment tax credits	192	92	257
Tax benefit of operating loss carryforwards	0	0	0
Investment tax credits	0	0	0
State	24	10	37
Total deferred expense	216	102	294
Amortization of deferred investment tax credits	0	0	0
Total income tax expense	$334	$301	$288

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)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Contingency [Line Items]
U.S. statutory rate	35.00%	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	0.00%	2.10%	4.20%
Investment tax credits	-8.60%	-1.80%	0.00%
Production tax credits	-1.20%	-0.60%	-0.50%
Valuation allowances	0.70%	-0.10%	-0.70%
AFUDC - equity	0.00%	-0.60%	-0.90%
Employee stock ownership plan deduction	-0.90%	-0.60%	-0.70%
Other, net	0.40%	-0.40%	-0.60%
Effective tax rate	25.40%	33.00%	35.80%
Virginia Electric and Power Company
Income Tax Contingency [Line Items]
U.S. statutory rate	35.00%	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.80%	3.10%	3.90%
Investment tax credits	0.00%	0.00%	0.00%
Production tax credits	-0.60%	-0.20%	0.00%
Valuation allowances	0.00%	0.00%	0.00%
AFUDC - equity	0.00%	-0.80%	-0.90%
Employee stock ownership plan deduction	0.00%	0.00%	0.00%
Other, net	0.80%	-0.40%	0.30%
Effective tax rate	39.00%	36.70%	38.30%
Dominion Gas Holdings, LLC
Income Tax Contingency [Line Items]
U.S. statutory rate	35.00%	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.40%	4.30%	3.40%
Investment tax credits	0.00%	0.00%	0.00%
Production tax credits	0.00%	0.00%	0.00%
Valuation allowances	0.00%	0.00%	0.00%
AFUDC - equity	0.00%	-0.10%	-0.60%
Employee stock ownership plan deduction	0.00%	0.00%	0.00%
Other, net	0.10%	0.30%	0.70%
Effective tax rate	39.50%	39.50%	38.50%

Income_Taxes_The_Companies_Def

Income Taxes (The Companies Deferred Income Taxes Components) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Income Tax Contingency [Line Items]
Total deferred income tax assets	$2,023	$2,142
Total deferred income tax liabilities	8,663	8,463
Total net deferred income tax liabilities	6,640	6,321
Total deferred income taxes:
Plant and equipment, primarily depreciation method and basis differences	5,895	5,383
Nuclear decommissioning	1,241	1,136
Deferred state income taxes	659	606
Federal benefit of deferred state income taxes	-231	-212
Deferred fuel, purchased energy and gas costs	27	-33
Pension benefits	272	435
Other postretirement benefits	-17	-78
Loss and credit carryforwards	-1,434	-797
Valuation allowances	87	69
Partnership basis differences	304	125
Other	-163	-313
Total net deferred income tax liabilities	6,640	6,321
Virginia Electric and Power Company
Income Tax Contingency [Line Items]
Total deferred income tax assets	500	462
Total deferred income tax liabilities	4,915	4,498
Total net deferred income tax liabilities	4,415	4,036
Total deferred income taxes:
Plant and equipment, primarily depreciation method and basis differences	3,965	3,628
Nuclear decommissioning	474	441
Deferred state income taxes	299	285
Federal benefit of deferred state income taxes	-105	-100
Deferred fuel, purchased energy and gas costs	18	-50
Pension benefits	-77	-52
Other postretirement benefits	13	-3
Loss and credit carryforwards	-116	-106
Valuation allowances	0	0
Partnership basis differences	0	0
Other	-56	-7
Total net deferred income tax liabilities	4,415	4,036
Dominion Gas Holdings, LLC
Income Tax Contingency [Line Items]
Total deferred income tax assets	227	216
Total deferred income tax liabilities	2,289	2,103
Total net deferred income tax liabilities	2,062	1,887
Total deferred income taxes:
Plant and equipment, primarily depreciation method and basis differences	1,417	1,266
Nuclear decommissioning	0	0
Deferred state income taxes	207	182
Federal benefit of deferred state income taxes	-72	-64
Deferred fuel, purchased energy and gas costs	7	13
Pension benefits	567	522
Other postretirement benefits	-12	-13
Loss and credit carryforwards	-10	-10
Valuation allowances	0	0
Partnership basis differences	42	42
Other	-84	-51
Total net deferred income tax liabilities	$2,062	$1,887

Income_Taxes_Unrecognized_Tax_

Income Taxes (Unrecognized Tax Benefits) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1	$222	$293	$347
Increases-prior period positions	24	17	28
Decreases-prior period positions	-26	-99	-106
Increases-current period positions	16	30	43
Decreases-current period positions	0	-5	0
Settlements with tax authorities	0	-2	-4
Expiration of statutes of limitations	-91	-12	-15
Balance at December 31	145	222	293
Virginia Electric and Power Company
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1	39	57	114
Increases-prior period positions	2	12	4
Decreases-prior period positions	-16	-42	-80
Increases-current period positions	11	14	24
Decreases-current period positions	0	0	0
Settlements with tax authorities	0	-2	-4
Expiration of statutes of limitations	0	0	-1
Balance at December 31	36	39	57
Dominion Gas Holdings, LLC
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1	29	30	30
Increases-prior period positions	0	0	0
Decreases-prior period positions	0	-1	0
Increases-current period positions	0	0	0
Decreases-current period positions	0	0	0
Settlements with tax authorities	0	0	0
Expiration of statutes of limitations	0	0	0
Balance at December 31	$29	$29	$30

Income_Taxes_Earliest_Tax_Year

Income Taxes (Earliest Tax Year) (Details)	12 Months Ended
	Dec. 31, 2014
Pennsylvania
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2010	[1]
Connecticut
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2011
Virginia
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2011	[2]
West Virginia
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2011	[1]
New York
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2007	[1]
[1]	Considered a major state for Dominion Gas' operations.
[2]	Considered a major state for Virginia Power's operations.

Income_Taxes_Income_Taxes_Sche

Income Taxes Income Taxes (Schedule of Income Tax Expense from Discontinued Operations) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Current:
Federal	($274)	($248)
State	-41	-6
Total current benefit	-315	-254
Deferred:
Federal	232	-368
State	40	-70
Total deferred expense (benefit)	272	-438
Total income tax benefit	($43)	($692)

Fair_Value_Measurements_Narrat

Fair Value Measurements (Narrative) (Details) (USD $)	3 Months Ended	12 Months Ended	1 Months Ended	3 Months Ended	12 Months Ended	3 Months Ended	1 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2013	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2014	Sep. 30, 2012	Jun. 30, 2012
			Project
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment charge after tax	$33
Impairment charge		1,600
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment charge					55
Impairment charge after tax					33
Impairment charge, net of tax				33
Number of development projects canceled			2
Severance costs					14
Severance costs net of tax					8
Kewaunee
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number of utilities					2
Elwood
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Ownership percentage							50.00%
Fair Value, Measurements, Nonrecurring | Dominion Gas Holdings, LLC | Other operations and maintenance expense
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment charge			6			9
Impairment charge, net of tax			4			6
Fair Value, Measurements, Nonrecurring | Kewaunee
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment charge							378
Long-lived assets impairment charges, net of tax							244
Inventory write-down							33
Inventory write down, net of tax							21
Severance costs							24
Severance costs net of tax							16
Fair Value, Measurements, Nonrecurring | Kewaunee | Other operations and maintenance expense
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment and other charges, net of tax							281
Impairment and other charges							435
Fair Value, Measurements, Nonrecurring | Salem Harbor | Loss from Discontinued Operations
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
After tax charge on disposal of assets								27
Pretax charge on disposal of assets								16
Fair Value, Measurements, Nonrecurring | Brayton Point and Kincaid | Loss from Discontinued Operations
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment charge		1,600
Impairment and other charges, net of tax		1,000
Fair Value, Measurements, Nonrecurring | Brayton Point and Kincaid | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long lived assets estimated fair value		216
Gas, Transmission and Distribution Equipment | Fair Value, Measurements, Nonrecurring | Other operations and maintenance expense
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment charge			49
Impairment charge after tax			29
Gas, Transmission and Distribution Equipment | Fair Value, Measurements, Nonrecurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Estimated fair value	$1		1

Fair_Value_Measurements_Fair_V

Fair Value Measurements (Fair Value, Option, Quantitative Disclosures) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$719		$890
Derivative liabilities	794		1,102
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	125
Derivative liabilities	18
Level 3 | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	74	[1]
Derivative liabilities	12	[1]
Level 3 | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	5
Derivative liabilities	2
Level 3 | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	44
Derivative liabilities	4
Level 3 | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	[2]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-2	[3]
Credit spread	1.00%	[4]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Minimum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	2	[3]
Price Volatility	19.00%	[5]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Minimum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-1	[3]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Minimum | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	0	[3]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Weighted Average | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-1	[3],[6]
Credit spread	2.00%	[4],[6]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Weighted Average | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	3	[3],[6]
Price Volatility	33.00%	[5],[6]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Weighted Average | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	3	[3],[6]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Weighted Average | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	1	[3],[6]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	11	[3]
Credit spread	5.00%	[4]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Maximum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	4	[3]
Price Volatility	67.00%	[5]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Maximum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	21	[3]
Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Maximum | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	2	[3]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-2	[3]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Minimum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	2	[3]
Price Volatility	19.00%	[5]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Minimum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-21	[3]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Weighted Average | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	2	[3],[6]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Weighted Average | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	3	[3],[6]
Price Volatility	33.00%	[5],[6]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Weighted Average | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	0	[3],[6]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	4	[3]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Maximum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	4	[3]
Price Volatility	67.00%	[5]
Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Maximum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	21	[3]
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	113		53
Derivative liabilities	87		12
Virginia Electric and Power Company | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	106
Derivative liabilities	4
Virginia Electric and Power Company | Level 3 | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	62	[1]
Virginia Electric and Power Company | Level 3 | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	44
Derivative liabilities	$4
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-2	[2]
Credit spread	1.00%	[3]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Minimum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-1	[2]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Weighted Average | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-1	[3],[6]
Credit spread	2.00%	[4],[6]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Weighted Average | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	3	[3],[6]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	7	[2]
Credit spread	5.00%	[3]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Assets | Maximum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	21	[2]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	-21	[2]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Weighted Average | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	0	[3],[6]
Virginia Electric and Power Company | Level 3 | Fair Value, Option, Quantitative Disclosures, Liabilities | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price	21	[2]
[1]	Includes basis.
[2]	Information represents Dominion Gas quantitative information about Level 3 fair value measurements.
[3]	Represents market prices beyond defined terms for Levels 1 and 2.
[4]	Represents credit spreads unrepresented in published markets.
[5]	Represents volatilities unrepresented in published markets.
[6]	Averages weighted by volume.

Fair_Value_Measurements_Assets

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$719		$890
Derivative liabilities	794		1,102
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	125
Derivative liabilities	18
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	4,938		4,791
Total liabilities	794		1,102
Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	695		753
Derivative liabilities	592		1,102
Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	24		137
Derivative liabilities	202
Fair Value, Measurements, Recurring | Equity securities: | Large Cap | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	2,669	[1]	2,417	[1]
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	12	[1]	13	[1]
Fair Value, Measurements, Recurring | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	6	[1]	79	[1]
Fair Value, Measurements, Recurring | Fixed Income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	441	[1]	345	[1]
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	609	[1]	590	[1]
Fair Value, Measurements, Recurring | Fixed Income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	395	[1]	343	[1]
Fair Value, Measurements, Recurring | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	74	[1]	3	[1]
Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	13	[1]	103	[1]
Fair Value, Measurements, Recurring | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			8	[1]
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	3,112		2,927
Total liabilities	3		3
Fair Value, Measurements, Recurring | Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3		3
Derivative liabilities	3		3
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
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	2,669	[1]	2,417	[1]
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	12	[1]	13	[1]
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	6	[1]	79	[1]
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	[1]	0	[1]
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	419	[1]	415	[1]
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	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 1 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	3	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 1 | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0	[1]
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	1,701		1,832
Total liabilities	773		1,051
Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	567		718
Derivative liabilities	571		1,051
Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	24		137
Derivative liabilities	202
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	[1]	0	[1]
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	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	441	[1]	345	[1]
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	190	[1]	175	[1]
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	395	[1]	343	[1]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	74	[1]	3	[1]
Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	10	[1]	103	[1]
Fair Value, Measurements, Recurring | Level 2 | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			8	[1]
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	125		32
Total liabilities	18		48
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	125		32
Derivative liabilities	18		48
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
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	[1]	0	[1]
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	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]	0	[1]
Fair Value, Measurements, Recurring | Level 3 | Restricted cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0	[1]
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	113		53
Derivative liabilities	87		12
Virginia Electric and Power Company | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	106
Derivative liabilities	4
Virginia Electric and Power Company | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	1,952		1,716
Total liabilities	87		12
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	113		5
Derivative liabilities	15		12
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			48
Derivative liabilities	72
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	1,157	[1]	1,021	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			36	[1]
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	250	[1]	191	[1]
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	198	[1]	212	[1]
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	211	[1]	164	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	23	[1]
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			31	[1]
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			8	[1]
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	1,294		1,203
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	1,157	[1]	1,021	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			36	[1]
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	[1]	0	[1]
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	137	[1]	146	[1]
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	[1]	0	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]
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	[1]
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	[1]
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	552		511
Total liabilities	83		3
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	7		3
Derivative liabilities	11		3
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			48
Derivative liabilities	72
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	[1]	0	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0	[1]
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	250	[1]	191	[1]
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	61	[1]	66	[1]
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	211	[1]	164	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	23	[1]
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			31	[1]
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			8	[1]
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	106		2
Total liabilities	4		9
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	106		2
Derivative liabilities	4		9
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	[1]	0	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0	[1]
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	[1]	0	[1]
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	[1]	0	[1]
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	[1]	0	[1]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	[1]
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	[1]
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	[1]
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	2		40
Total liabilities	9
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2		6
Derivative liabilities			25
Total liabilities			25
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets			34
Derivative liabilities	9
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	0		0
Total liabilities	0
Dominion Gas Holdings, LLC | 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
Total liabilities			0
Dominion Gas Holdings, LLC | 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
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	0		34
Total liabilities	9
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0		0
Derivative liabilities			13
Total liabilities			13
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets			34
Derivative liabilities	9
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	2		6
Total liabilities	0
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2		6
Derivative liabilities			12
Total liabilities			12
Dominion Gas Holdings, LLC | 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
[1]	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 $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Included in earnings	$97	($9)	($15)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	6	0	42
Commodity | Level 3
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	6	0	42
Commodity | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Beginnning balance	-16	25	-71
Included in earnings	97	-9	-15
Included in regulatory assets/liabilities	109	-9	30
Included in other comprehensive income (loss)	7	1	101
Settlements	-88	-23	47
Transfers out of Level 3	-2	-1	-67
Ending balance	107	-16	25
Commodity | Virginia Electric and Power Company | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Beginnning balance	-7	2	-28
Included in earnings	96	-17	-50
Included in regulatory assets/liabilities	109	-9	30
Settlements	-96	17	50
Ending balance	102	-7	2
Commodity | Dominion Gas Holdings, LLC | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Beginnning balance	-6	-12	-98
Included in earnings	2	1	-15
Included in other comprehensive income (loss)	10	3	86
Settlements	-4	2	15
Ending balance	$2	($6)	($12)

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Gains and Losses Included in the Level 3 Fair Value Category) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	$97	($9)	($15)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	6	0	42
Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	4	11	35
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	4	1	42
Electric Fuel and Energy Purchases
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	97	-19	-50
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	1	0	0
Purchased Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	-4	-1	0
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	$1	($1)	$0

Fair_Value_Measurements_Financ

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year			$23,200
Subsidiary preferred stock	257		0
Valuation of certain fair value hedges	55		19
Deferred issuance expenses	2
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	18,396	[1]	19,723	[1]
Junior subordinated notes	1,373	[2]	1,374	[2]
Remarketable subordinated notes	1,080	[2]	2,083	[2]
Subsidiary preferred stock	257	[3]	0	[3]
Estimated Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	19,887	[1],[4]	21,881	[1],[4]
Junior subordinated notes	1,394	[2],[4]	1,396	[2],[4]
Remarketable subordinated notes	1,192	[2],[4]	2,362	[2],[4]
Subsidiary preferred stock	261	[3],[4]	0	[3],[4]
Virginia Electric and Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year			8,935
Subsidiary preferred stock	257		0
Virginia Electric and Power Company | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	8,032	[2]	8,937	[2]
Subsidiary preferred stock	257	[3]	0	[3]
Virginia Electric and Power Company | Estimated Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	8,897	[2],[4]	10,293	[2],[4]
Subsidiary preferred stock	261	[3],[4]	0	[3],[4]
Dominion Gas Holdings, LLC
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year			2,600
Dominion Gas Holdings, LLC | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	1,198	[2]	2,594	[2]
Dominion Gas Holdings, LLC | Estimated Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	$1,169	[2],[4]	$2,672	[2],[4]
[1]	Carrying amount includes amounts which represent the unamortized discount and/or premium. At December 31, 2014, and 2013, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of approximately $19 million and $55 million, respectively.
[2]	Carrying amount includes amounts which represent the unamortized discount and/or premium.
[3]	Includes deferred issuance expenses of $2 million at December 31, 2013. See Note 18 for information about the redemption of preferred stock in 2014.
[4]	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.

Derivatives_and_Hedge_Accounti2

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$704	$883
Total derivatives, not subject to a master netting or similar arrangement	15	7
Derivative Asset	719	890
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	348	568
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	34	0
Net Amounts	322	315
Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	24	137
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	16	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	8	137
Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	382	240
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	34	63
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	34	0
Net Amounts	314	177
Commodity | Exchange
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	298	506
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	298	505
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	0	1
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	106	53
Total derivatives, not subject to a master netting or similar arrangement	7	0
Derivative Asset	113	53
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	102	49
Virginia Electric and Power Company | Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	0	48
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	0	48
Virginia Electric and Power Company | Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	106	4
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	102	0
Virginia Electric and Power Company | Commodity | Exchange
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	0	1
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	0	1
Dominion Gas Holdings, LLC
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	2	40
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	2	34
Dominion Gas Holdings, LLC | Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	0	34
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	0	34
Dominion Gas Holdings, LLC | 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
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	$2	$0

Derivatives_and_Hedge_Accounti3

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$782	$1,100
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Total derivatives, not subject to a master netting or similar arrangement	12	2
Derivative liabilities	794	1,102
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	348	568
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	196	402
Net Amounts	238	130
Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	202	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	16	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	186	0
Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	87	262
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	34	63
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	1	69
Net Amounts	52	130
Commodity | Exchange
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	493	838
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	298	505
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	195	333
Net Amounts	0	0
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	80	12
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Total derivatives, not subject to a master netting or similar arrangement	7	0
Derivative liabilities	87	12
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	7
Net Amounts	76	1
Virginia Electric and Power Company | Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	72	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	72	0
Virginia Electric and Power Company | Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	8	12
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	7
Net Amounts	4	1
Dominion Gas Holdings, LLC
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	9	25
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	9	19
Dominion Gas Holdings, LLC | Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	9	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	9	0
Dominion Gas Holdings, LLC | Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	0	25
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	$0	$19

Derivatives_and_Hedge_Accounti4

Derivatives and Hedge Accounting Activities (Volume of our Derivative Activity) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Current
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate	$1,300
Current | Natural Gas (bcf): | Fixed Price
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	52,000,000,000	[1]
Current | Natural Gas (bcf): | Basis
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	227,000,000,000
Current | Electricity (MWh): | Fixed Price
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (in Megawatt hours)	14,689,432
Current | Electricity (MWh): | FTRs
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (in Megawatt hours)	35,786,150
Current | Capacity (MW)
Derivative Instruments, Gain (Loss) [Line Items]
Capacity of Electricity (in Megawatts)	10,700
Current | Liquids (gallons)
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	39,984,000	[2]
Noncurrent
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate	4,450
Noncurrent | Natural Gas (bcf): | Fixed Price
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	13,000,000,000	[1]
Noncurrent | Natural Gas (bcf): | Basis
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	575,000,000,000
Noncurrent | Electricity (MWh): | Fixed Price
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (in Megawatt hours)	6,148,800
Noncurrent | Electricity (MWh): | FTRs
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (in Megawatt hours)	0
Noncurrent | Capacity (MW)
Derivative Instruments, Gain (Loss) [Line Items]
Capacity of Electricity (in Megawatts)	7,600
Noncurrent | Liquids (gallons)
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	1,260,000	[2]
Virginia Electric and Power Company | Current
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate	550
Virginia Electric and Power Company | Current | Natural Gas (bcf): | Fixed Price
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	7,000,000,000
Virginia Electric and Power Company | Current | Natural Gas (bcf): | Basis
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	51,000,000,000
Virginia Electric and Power Company | Current | Electricity (MWh): | FTRs
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (in Megawatt hours)	33,709,386
Virginia Electric and Power Company | Current | Capacity (MW)
Derivative Instruments, Gain (Loss) [Line Items]
Capacity of Electricity (in Megawatts)	10,700
Virginia Electric and Power Company | Noncurrent
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate	900
Virginia Electric and Power Company | Noncurrent | Natural Gas (bcf): | Fixed Price
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	0
Virginia Electric and Power Company | Noncurrent | Natural Gas (bcf): | Basis
Derivative Instruments, Gain (Loss) [Line Items]
Volume of natural gas (in billion cubic feet and gallons)	493,000,000,000
Virginia Electric and Power Company | Noncurrent | Electricity (MWh): | FTRs
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (in Megawatt hours)	0
Virginia Electric and Power Company | Noncurrent | Capacity (MW)
Derivative Instruments, Gain (Loss) [Line Items]
Capacity of Electricity (in Megawatts)	7,600
Dominion Gas Holdings, LLC | Current
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate	0
Dominion Gas Holdings, LLC | Current | Capacity (MW)
Derivative Instruments, Gain (Loss) [Line Items]
Capacity of Electricity (in Megawatts)	32,340,000
Dominion Gas Holdings, LLC | Noncurrent
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate	$250
Dominion Gas Holdings, LLC | Noncurrent | Capacity (MW)
Derivative Instruments, Gain (Loss) [Line Items]
Capacity of Electricity (in Megawatts)	0
[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 $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	($178)	($288)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	33
Commodity | Electricity
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	56
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	46
Maximum Term	24 months
Commodity | Gas
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	-8
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	-7
Maximum Term	27 months
Commodity | Other
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	0
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	0
Maximum Term	17 months
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	-226
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	-6
Maximum Term	384 months
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	-20	3
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	0
Dominion Gas Holdings, LLC | Commodity | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	0
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	0
Maximum Term	3 months
Dominion Gas Holdings, LLC | Commodity | Other
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	0
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	0
Maximum Term	12 months
Dominion Gas Holdings, LLC | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	-20
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$0
Maximum Term	360 months

Derivatives_and_Hedge_Accounti6

Derivatives and Hedge Accounting Activities (Fair Values of our Derivatives) (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	$719		$890
Total Fair Value, Liabilities	794		1,102
Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	536		687
Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	523		571
Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	13		116
Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	183	[1]	203	[1]
Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	172		182
Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	11		21
Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	591		828
Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	491		828
Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	100
Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	203	[2]	274	[2]
Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	101		274
Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	102
Fair Value - Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	376		214
Total Fair Value, Liabilities	481		386
Fair Value - Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	294		165
Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	281		49
Fair Value - Derivatives under Hedge Accounting | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	13		116
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	82	[1]	49	[1]
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	71		28
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	11		21
Fair Value - Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	324		267
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	224		267
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	100
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	157	[2]	119	[2]
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	55		119
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	102
Fair Value - Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	343		676
Total Fair Value, Liabilities	313		716
Fair Value - Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	242		522
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	242		522
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	101	[1]	154	[1]
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	101		154
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	267		561
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	267		561
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	0
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	46	[2]	155	[2]
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	46		155
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	0
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	113		53
Total Fair Value, Liabilities	87		12
Virginia Electric and Power Company | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	51	[3]	53	[3]
Virginia Electric and Power Company | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	51		5
Virginia Electric and Power Company | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets			48
Virginia Electric and Power Company | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	62	[4]
Virginia Electric and Power Company | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	62
Virginia Electric and Power Company | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	60		12
Virginia Electric and Power Company | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	15		12
Virginia Electric and Power Company | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	45
Virginia Electric and Power Company | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	27	[5]
Virginia Electric and Power Company | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	27
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	0		50
Total Fair Value, Liabilities	75		1
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	0	[3]	50	[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	0		2
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			48
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	0	[4]
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	0
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	48		1
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		1
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	45
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	27	[5]
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	27
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	113		3
Total Fair Value, Liabilities	12		11
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	51	[3]	3	[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	51		3
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 | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	62	[4]
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	62
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	12		11
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	12		11
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 | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	0
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	2		40
Total Fair Value, Liabilities	9		25
Dominion Gas Holdings, LLC | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	2	[6]	40	[6]
Dominion Gas Holdings, LLC | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	2		6
Dominion Gas Holdings, LLC | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets			34
Dominion Gas Holdings, LLC | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities			25	[7]
Dominion Gas Holdings, LLC | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities			25
Dominion Gas Holdings, LLC | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	9	[8]
Dominion Gas Holdings, LLC | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	9
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	2		40
Total Fair Value, Liabilities	9		25
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	2	[6]	40	[6]
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	2		6
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets			34
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities			25	[7]
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities			25
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	9	[8]
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	9
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	0		0
Total Fair Value, Liabilities	0		0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	0	[6]	0	[6]
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets	0		0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Assets			0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities			0	[7]
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities			0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Total Fair Value, Liabilities	0	[8]
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
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]	Noncurrent derivative assets are presented in other deferred charges and other assets 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.
[6]	Current derivative assets are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.
[7]	Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.
[8]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.

Derivatives_and_Hedge_Accounti7

Derivatives and Hedge Accounting Activities (Gains and Losses on our Derivatives in Cash Flow Hedging Relationships) (Details) (Cash Flow Hedges, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	$37	[1]	($404)	[1]	($13)	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	-152		-130		94
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	-85	[2]	86	[2]	-25	[2]
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	245	[1]	-481	[1]	71	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	-136		-115		96
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	-4	[2]	5	[2]	10	[2]
Commodity | Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income	-130		-58		188
Commodity | Purchased gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income	-13		-47		-75
Commodity | Electric fuel and other energy-related purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income	7		-10		-17
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	-208	[1],[3]	77	[1],[3]	-84	[1],[3]
Amount of Gain (Loss) Reclassified from AOCI to Income	-16	[3]	-15	[3]	-2	[3]
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	-81	[2],[3]	81	[2],[3]	-35	[2],[3]
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	-6	[4]	9	[4]	-8	[4]
Amount of Gain (Loss) Reclassified from AOCI to Income	5		0		-4
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	-85	[5]	86	[5]	-25	[5]
Virginia Electric and Power Company | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	4	[4]	0	[4]	-2	[4]
Amount of Gain (Loss) Reclassified from AOCI to Income	5		0		-4
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	-4	[5]	5	[5]	10	[5]
Virginia Electric and Power Company | Commodity | Electric Fuel and Energy Purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income	5		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)	-10	[4],[6]	9	[4],[6]	-6	[4],[6]
Amount of Gain (Loss) Reclassified from AOCI to Income	0	[6]	0	[6]	0	[6]
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	-81	[5],[6]	81	[5],[6]	-35	[5],[6]
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	-50	[7]	66	[7]	23	[7]
Amount of Gain (Loss) Reclassified from AOCI to Income	-13		-16		-33
Dominion Gas Holdings, LLC | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	12	[7]	-2	[7]	64	[7]
Amount of Gain (Loss) Reclassified from AOCI to Income	-12		-16		-33
Dominion Gas Holdings, LLC | Commodity | Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income	2		-2		-15
Dominion Gas Holdings, LLC | Commodity | Purchased gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income	-14		-14		-18
Dominion Gas Holdings, LLC | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	-62	[7],[8]	68	[7],[8]	-41	[7],[8]
Amount of Gain (Loss) Reclassified from AOCI to Income	($1)	[8]	$0	[8]	$0	[8]
[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.
[7]	Amounts deferred into AOCI have no associated effect in Dominion Gas' Consolidated Statements of Income.
[8]	Amounts recorded in Dominion Gas' Consolidated Statements of Income are classified in interest and related charges.

Derivatives_and_Hedge_Accounti8

Derivatives and Hedge Accounting Activities (Gains and Losses on our Derivatives Not Designated as Hedging Instruments) (Details) (Derivatives not designated as hedging instruments, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	($248)	[1]	($83)	[1]	$131	[1]
Commodity | Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	-310	[1]	-45	[1]	168	[1]
Commodity | Purchased gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	-51	[1]	-9	[1]	-14	[1]
Commodity | Electric fuel and other energy-related purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	113	[1]	-29	[1]	-40	[1]
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	0	[1],[2]	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	105	[3]	-16	[3]	-50	[3]
Virginia Electric and Power Company | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	$105	[3],[4]	($16)	[3],[4]	($50)	[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 electric fuel and other energy-related purchases.

Earnings_Per_Share_Calculation

Earnings Per Share (Calculation of our Basic and Diluted EPS) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Earnings Per Share [Abstract]
Net income attributable to Dominion	$243	$529	$159	$379	$431	$569	$202	$495	$1,310		$1,697		$302
Average shares of common stock outstanding-Basic									582,700,000		578,700,000		572,900,000
Net effect of potentially dilutive securities									1,800,000	[1]	800,000	[1]	1,000,000	[1]
Average shares of common stock outstanding-Diluted									584,500,000		579,500,000		573,900,000
Earnings Per Common Share-Basic (in dollars per share)	$0.42	$0.91	$0.27	$0.65	$0.74	$0.98	$0.35	$0.86	$2.25		$2.93		$0.53
Earnings Per Common Share-Diluted (in dollars per share)	$0.42	$0.90	$0.27	$0.65	$0.74	$0.98	$0.35	$0.86	$2.24		$2.93		$0.53
Potentially dilutive securities excluded from the calculation of diluted EPS													0
[1]	Dilutive securities consist primarily of contingently convertible senior notes and the 2013 Equity Units for 2014 and contingently convertible senior notes for 2013 and 2012. Dominion redeemed all of its contingently convertible senior notes in 2014. See Note 17 for more information.

Investments_Narrative_Details

Investments (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended		3 Months Ended	1 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 31, 2014	Dec. 31, 2012	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Sep. 30, 2014	Dec. 31, 2013
									mi
									Member
Gain (Loss) on Investments [Line Items]
Equity earnings on investments	$46	$14	$25
Company received distribution from Fowler Ridge in connection with non-recourse permanent financing	60	33	58
Carrying amount of Company's investments exceeded its shares of underlying equity	126	36								36
Capitalized interest during construction	87
Equity method investment goodwill	39
Write off of goodwill	42	44
Blue Racer
Gain (Loss) on Investments [Line Items]
Company received distribution from Fowler Ridge in connection with non-recourse permanent financing	85	160	115		115
Ownership percentage	50.00%		50.00%		50.00%
Increase in equity method investment						473
Increase in equity method investment				155
Goodwill allocated from Dominion's Goodwill balance in its equity method investment in Blue Racer				6
Blue Racer | Pipelines
Gain (Loss) on Investments [Line Items]
Amount of consideration							84
Cash proceeds received from sale							84	47
Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline | Gas Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)									45.00%
Length of FERC regulated interstate natural gas pipeline									550
Number of members									4
Duration of contract									20 years
Atlantic Coast Pipeline | Pipelines | Duke Energy Corporation | Jointly Owned Natural Gas Pipeline | Gas Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)									40.00%
Atlantic Coast Pipeline | Pipelines | Piedmont Natural Gas Company | Jointly Owned Natural Gas Pipeline | Gas Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)									10.00%
Atlantic Coast Pipeline | Pipelines | AGL Resources Inc | Jointly Owned Natural Gas Pipeline | Gas Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)									5.00%
Other Income
Gain (Loss) on Investments [Line Items]
Equity earnings on investments	46	14	25
Other operations and maintenance expense | Blue Racer
Gain (Loss) on Investments [Line Items]
Gain on purchase of business					72
Gain on purchase of business, net of tax					43
Transaction costs on sale			9		9
Other operations and maintenance expense | Blue Racer | Pipelines
Gain (Loss) on Investments [Line Items]
Gain from sale								25		4
After tax gain on sale							34	14		2
Write off of goodwill								2
Dominion Gas Holdings, LLC
Gain (Loss) on Investments [Line Items]
Equity earnings on investments	21	22	23
Company received distribution from Fowler Ridge in connection with non-recourse permanent financing	20	19	25
Carrying amount of Company's investments exceeded its shares of underlying equity	8	8								8
Write off of goodwill	3	7
Dominion Gas Holdings, LLC | Blue Racer
Gain (Loss) on Investments [Line Items]
Company received distribution from Fowler Ridge in connection with non-recourse permanent financing	1	78	0
Extinguishment of affiliated current borrowings					187
Dominion Gas Holdings, LLC | Blue Racer | Pipelines
Gain (Loss) on Investments [Line Items]
Number of pipelines sold					2
Amount of consideration			248		248
Cash proceeds received from sale					61	78	17			30
Extinguishment of affiliated current borrowings							67
Dominion Gas Holdings, LLC | Other Income
Gain (Loss) on Investments [Line Items]
Equity earnings on investments	21	22	23
Dominion Gas Holdings, LLC | Other operations and maintenance expense | Blue Racer | Pipelines
Gain (Loss) on Investments [Line Items]
Gain from sale					176	74	59			3
After tax gain on sale					110	41	35			2
Write off of goodwill							3
Categories of Investments, Marketable Securities, Trading Securities
Gain (Loss) on Investments [Line Items]
Investments held in our rabbi trusts	110	107								107
Cost method investments
Gain (Loss) on Investments [Line Items]
Investments held in our rabbi trusts	$6	$10								$10

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 $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Investment Holdings [Line Items]
Total Unrealized Gains	$1,408	[1]	$1,252	[1]
Total Unrealized Losses	-6	[1],[2]	-18	[1],[2]
Nuclear decommissioning trust funds	4,196		3,903
Total Amortized Cost	2,794		2,669
Net assets related to pending sales and purchases of securities	3		11
Fair value of securities in an unrealized loss position	379		604
Virginia Electric and Power Company
Investment Holdings [Line Items]
Total Unrealized Gains	619	[1]	538	[1]
Total Unrealized Losses	-3	[1],[3]	-9	[1],[3]
Nuclear decommissioning trust funds	1,930		1,765
Total Amortized Cost	1,314		1,236
Net assets related to pending sales and purchases of securities	6		6
Fair value of securities in an unrealized loss position	170		299
Cost method investments
Investment Holdings [Line Items]
Other investments and securities, at cost	86		106
Total Unrealized Gains	0	[1]	0	[1]
Total Unrealized Losses	0	[1]	0	[1]
Nuclear decommissioning trust funds	86		106
Cost method investments | Virginia Electric and Power Company
Investment Holdings [Line Items]
Other investments and securities, at cost	86		106
Total Unrealized Gains	0	[1]	0	[1]
Total Unrealized Losses	0	[1]	0	[1]
Nuclear decommissioning trust funds	86		106
Cash equivalents and other
Investment Holdings [Line Items]
Other investments and securities, at cost	16	[4]	110	[4]
Total Unrealized Gains	0	[1],[4]	0	[1],[4]
Total Unrealized Losses	0	[1],[4]	0	[1],[4]
Nuclear decommissioning trust funds	16	[4]	110	[4]
Cash equivalents and other | Virginia Electric and Power Company
Investment Holdings [Line Items]
Other investments and securities, at cost	6	[5]	37	[5]
Total Unrealized Gains	0	[1],[5]	0	[1],[5]
Total Unrealized Losses	0	[1],[5]	0	[1],[5]
Nuclear decommissioning trust funds	6	[5]	37	[5]
Corporate debt instruments
Investment Holdings [Line Items]
Amortized Cost	424		332
Total Unrealized Gains	19	[1]	16	[1]
Total Unrealized Losses	-2	[1]	-3	[1]
Nuclear decommissioning trust funds	441		345
Corporate debt instruments | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost	242		185
Total Unrealized Gains	9	[1]	8	[1]
Total Unrealized Losses	-1	[1]	-2	[1]
Nuclear decommissioning trust funds	250		191
U.S. Treasury securities and agency debentures
Investment Holdings [Line Items]
Amortized Cost	597		589
Total Unrealized Gains	13	[1]	8	[1]
Total Unrealized Losses	-4	[1]	-10	[1]
Nuclear decommissioning trust funds	606		587
U.S. Treasury securities and agency debentures | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost	197		214
Total Unrealized Gains	3	[1]	1	[1]
Total Unrealized Losses	-2	[1]	-3	[1]
Nuclear decommissioning trust funds	198		212
State and municipal
Investment Holdings [Line Items]
Amortized Cost	332		297
Total Unrealized Gains	23	[1]	11	[1]
Total Unrealized Losses	0	[1]	-5	[1]
Nuclear decommissioning trust funds	355		303
State and municipal | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost	197		163
Total Unrealized Gains	13	[1]	4	[1]
Total Unrealized Losses	0	[1]	-4	[1]
Nuclear decommissioning trust funds	210		163
Other securities
Investment Holdings [Line Items]
Amortized Cost	66		3
Total Unrealized Gains	0	[1]	0	[1]
Total Unrealized Losses	0	[1]	0	[1]
Nuclear decommissioning trust funds	66		3
Other securities | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost	23
Total Unrealized Gains	0	[1]
Total Unrealized Losses	0	[1]
Nuclear decommissioning trust funds	23
U.S.: | Equity securities: | Large Cap
Investment Holdings [Line Items]
Amortized Cost	1,273		1,183
Total Unrealized Gains	1,353	[1]	1,194	[1]
Total Unrealized Losses	0	[1]	0	[1]
Nuclear decommissioning trust funds	2,626		2,377
U.S.: | Equity securities: | Large Cap | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost	563		506
Total Unrealized Gains	594	[1]	514	[1]
Total Unrealized Losses	0	[1]	0	[1]
Nuclear decommissioning trust funds	1,157		1,020
U.S.: | Equity securities: | Other
Investment Holdings [Line Items]
Amortized Cost			49
Total Unrealized Gains			23	[1]
Total Unrealized Losses			0	[1]
Nuclear decommissioning trust funds			72
U.S.: | Equity securities: | Other | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost			25
Total Unrealized Gains			11	[1]
Total Unrealized Losses			0	[1]
Nuclear decommissioning trust funds			$36
[1]	Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
[2]	The fair value of securities in an unrealized loss position was $379 million and $604 million at December 31, 2014 and 2013, respectively.
[3]	The fair value of securities in an unrealized loss position was $170 million and $299 million at December 31, 2014 and 2013, respectively.
[4]	Includes pending sales of securities of $3 million and $11 million at December 31, 2014 and 2013, respectively.
[5]	Includes pending sales of securities of $6 million at December 31, 2014 and 2013.

Investments_Fair_Value_of_our_

Investments (Fair Value of our Marketable Debt Securities by Contractual Maturity) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Schedule of Available-for-sale Securities [Line Items]
Due in one year or less	$169
Due after one year through five years	390
Due after five years through ten years	426
Due after ten years	483
Total	1,468
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Due in one year or less	40
Due after one year through five years	180
Due after five years through ten years	242
Due after ten years	219
Total	$681

Investments_Selected_Informati

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Available-for-sale securities:
Proceeds from sales	$1,235		$1,476		$1,356
Realized gains	171	[1]	157	[1]	98	[1]
Realized losses	30	[1]	33	[1]	33	[1]
Virginia Electric and Power Company
Available-for-sale securities:
Proceeds from sales	549		572		626
Realized gains	73	[1]	52	[1]	42	[1]
Realized losses	$12	[1]	$14	[1]	$11	[1]
[1]	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.

Investments_Recorded_OtherThan

Investments (Recorded Other-Than-Temporary Impairment Losses on Investments) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Schedule of Available-for-sale Securities [Line Items]
Total other-than-temporary impairment losses	$21	[1]	$31	[1]	$26	[1]
Losses recorded to decommissioning trust regulatory liability	-5		-13		-10
Losses recognized in other comprehensive income (before taxes)	-3		-10		-2
Net impairment losses recognized in earnings	13		8		14
Other-than-temporary impairment losses for debt securities	3		18		4
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Total other-than-temporary impairment losses	8	[2]	15	[2]	11	[2]
Losses recorded to decommissioning trust regulatory liability	-4		-13		-10
Losses recognized in other comprehensive income (before taxes)	-2		-1		0
Net impairment losses recognized in earnings	2		1		1
Other-than-temporary impairment losses for debt securities	$2		$9		$2
[1]	Amounts include other-than-temporary impairment losses for debt securities of $3 million, $18 million and $4 million at December 31, 2014, 2013 and 2012, respectively.
[2]	Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018. Includes Dominion's investment in Atlantic Coast Pipeline. See Note 15 for more information.

Investments_Investments_Under_

Investments (Investments Under Equity Method of Accounting) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Investment Balance	$1,081		$916
Commitment to invest in clean power and technology	50
Blue Racer Midstream, LLC
Schedule of Equity Method Investments [Line Items]
Ownership%	50.00%				50.00%
Investment Balance	671		510
Description	Midstream gas and related services
Fowler I Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership%	50.00%
Investment Balance	134		149
Description	Wind-powered merchant generation facility
NedPower Mount Storm LLC
Schedule of Equity Method Investments [Line Items]
Ownership%	50.00%
Investment Balance	128		131
Description	Wind-powered merchant generation facility
Iroquois Gas Transmission System, LP
Schedule of Equity Method Investments [Line Items]
Ownership%	24.72%
Investment Balance	107		105
Description	Gas transmission system
Other
Schedule of Equity Method Investments [Line Items]
Investment Balance	41	[1]	21	[1]
Dominion Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Investment Balance	107		105
Dominion Gas Holdings, LLC | Iroquois Gas Transmission System, LP
Schedule of Equity Method Investments [Line Items]
Ownership%	24.72%
Investment Balance	$107		$105
Description	Gas transmission system
[1]	Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018. Includes Dominion's investment in Atlantic Coast Pipeline. See Note 15 for more information.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Narrative) (Details) (Dominion Gas Holdings, LLC, Oil and Gas Properties, USD $)	1 Months Ended			12 Months Ended
In Millions, unless otherwise specified	Nov. 30, 2014	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013
	Field	Field	Natural_Gas_Producer		acre
	acre	acre	acre
Dominion Gas Holdings, LLC | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Number of natural gas producers			2
Acres of Marcellus Shale development rights	11,000	24,000	100,000		100,000
Agreed upon payments for conveyance of acres of natural gas storage fields	$27	$120	$200		$200
Period for payments related to conveyance of natural gas storage fields		4 years	9 years
Cash proceeds received from sale	60			16	100
Gain from sale	60				20
After tax gain on sale	36				12
Total deferred revenue				$85
Number of natural gas storage fields	1	1
Number of acres included in initial conveyance	12,000

Property_Plant_and_Equipment_P

Property, Plant and Equipment (Property, Plant and Equipment) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Utility:
Generation	$15,193	$14,018
Transmission	9,897	8,686
Distribution	12,354	11,714
Storage	2,350	2,190
Nuclear fuel	1,411	1,375
Gas gathering and processing	791	787
General and other	845	812
Other-including plant under construction	3,633	3,261
Total utility	46,474	42,843
Nonutility:
Merchant generation-nuclear	1,267	1,153
Merchant generation-other	2,023	1,328
Nuclear fuel	860	770
Other-including plant under construction	782	875
Total nonutility	4,932	4,126
Total property, plant and equipment	51,406	46,969
Virginia Electric and Power Company
Utility:
Generation	15,193	14,018
Transmission	5,884	4,959
Distribution	9,526	9,103
Nuclear fuel	1,411	1,375
General and other	697	668
Other-including plant under construction	2,464	2,719
Total utility	35,175	32,842
Nonutility:
Total nonutility	5	6
Total property, plant and equipment	35,180	32,848
Dominion Gas Holdings, LLC
Utility:
Transmission	3,690	3,407
Distribution	2,530	2,333
Storage	1,466	1,314
Gas gathering and processing	786	783
General and other	111	103
Plant under construction	179	175
Total utility	8,762	8,115
Nonutility:
E&P properties being amortized and other	140	125
Total nonutility	140	125
Total property, plant and equipment	$8,902	$8,240

Property_Plant_and_Equipment_S

Property, Plant and Equipment (Share of Jointly-Owned Power Stations) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Millstone Unit 3
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest (percentage)	93.50%	[1]
Plant in service	$1,104	[1]
Accumulated depreciation	-290	[1]
Nuclear fuel	480	[1]
Accumulated amortization of nuclear fuel	-342	[1]
Plant under construction	71	[1]
Virginia Electric and Power Company | Bath County Pumped Storage Station
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest (percentage)	60.00%	[2]
Plant in service	1,039	[2]
Accumulated depreciation	-542	[2]
Nuclear fuel	0	[2]
Accumulated amortization of nuclear fuel	0	[2]
Plant under construction	11	[2]
Virginia Electric and Power Company | North Anna
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest (percentage)	88.40%	[2]
Plant in service	2,426	[2]
Accumulated depreciation	-1,137	[2]
Nuclear fuel	627	[2]
Accumulated amortization of nuclear fuel	-486	[2]
Plant under construction	114	[2]
Virginia Electric and Power Company | Clover Power Station
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest (percentage)	50.00%	[2]
Plant in service	573	[2]
Accumulated depreciation	-206	[2]
Nuclear fuel	0	[2]
Accumulated amortization of nuclear fuel	0	[2]
Plant under construction	$11	[2]
[1]	Unit jointly owned by Dominion.
[2]	Units jointly owned by Virginia Power.

Goodwill_and_Intangible_Assets1

Goodwill and Intangible Assets (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Goodwill [Line Items]
Amortization expense for intangible assets	$71	$72	$82
Acquisition of intangible assets	115
Weighted-average amortization period (years)	15 years
Virginia Electric and Power Company
Goodwill [Line Items]
Amortization expense for intangible assets	24	22	22
Acquisition of intangible assets	45
Weighted-average amortization period (years)	14 years
Dominion Gas Holdings, LLC
Goodwill [Line Items]
Amortization expense for intangible assets	17	16	15
Acquisition of intangible assets	$8
Weighted-average amortization period (years)	7 years

Goodwill_and_Intangible_Assets2

Goodwill and Intangible Assets (Goodwill) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Goodwill [Roll Forward]
Goodwill, Beginning Balance	$3,086	[1]	$3,130	[1]
Asset disposition adjustment	-42		-44
Goodwill, Ending Balance	3,044	[1]	3,086	[1]
Dominion Generation
Goodwill [Roll Forward]
Goodwill, Beginning Balance	1,484	[1]	1,503	[1]
Asset disposition adjustment	-32	[2]	-19	[2]
Goodwill, Ending Balance	1,452	[1]	1,484	[1]
Dominion Energy
Goodwill [Roll Forward]
Goodwill, Beginning Balance	676	[1]	701	[1]
Asset disposition adjustment	-10	[3]	-25	[3]
Goodwill, Ending Balance	666	[1]	676	[1]
DVP
Goodwill [Roll Forward]
Goodwill, Beginning Balance	926	[1]	926	[1]
Asset disposition adjustment	0		0
Goodwill, Ending Balance	926	[1]	926	[1]
Corporate and Other
Goodwill [Roll Forward]
Goodwill, Beginning Balance	0	[1],[4]	0	[1],[4]
Asset disposition adjustment	0	[4]	0	[4]
Goodwill, Ending Balance	0	[1],[4]	0	[1],[4]
Dominion Gas Holdings, LLC
Goodwill [Roll Forward]
Goodwill, Beginning Balance	545	[1]	552	[1]
Asset disposition adjustment	-3		-7
Goodwill, Ending Balance	542	[1]	545	[1]
Dominion Gas Holdings, LLC | Dominion Generation
Goodwill [Roll Forward]
Goodwill, Beginning Balance	0	[1]	0	[1]
Asset disposition adjustment	0		0
Goodwill, Ending Balance	0	[1]	0	[1]
Dominion Gas Holdings, LLC | Dominion Energy
Goodwill [Roll Forward]
Goodwill, Beginning Balance	545	[1]	552	[1]
Asset disposition adjustment	-3	[3]	-7	[3]
Goodwill, Ending Balance	542	[1]	545	[1]
Dominion Gas Holdings, LLC | DVP
Goodwill [Roll Forward]
Goodwill, Beginning Balance	0	[1]	0	[1]
Asset disposition adjustment	0		0
Goodwill, Ending Balance	0	[1]	0	[1]
Dominion Gas Holdings, LLC | Corporate and Other
Goodwill [Roll Forward]
Goodwill, Beginning Balance	0	[1],[4]	0	[1],[4]
Asset disposition adjustment	0	[4]	0	[4]
Goodwill, Ending Balance	$0	[1],[4]	$0	[1],[4]
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
[3]	Related to assets sold or contributed to an affiliate or Blue Racer.
[4]	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.

Goodwill_and_Intangible_Assets3

Goodwill and Intangible Assets (Components of Intangible Assets) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$887	$870
Accumulated Amortization	317	310
Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	286	271
Accumulated Amortization	81	78
Dominion Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	192	180
Accumulated Amortization	113	98
Software, licenses and other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	877	867
Accumulated Amortization	312	308
Software, licenses and other | Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	286	271
Accumulated Amortization	81	78
Software, licenses and other | Dominion Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	192	180
Accumulated Amortization	113	98
Emissions allowances
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	10	3
Accumulated Amortization	$5	$2

Goodwill_and_Intangible_Assets4

Goodwill and Intangible Assets (Annual Amortization Expense of Intangible Assets) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]
2015	$72
2016	67
2017	58
2018	45
2019	36
Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
2015	21
2016	18
2017	15
2018	12
2019	8
Dominion Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
2015	17
2016	16
2017	13
2018	11
2019	$11

Regulatory_Assets_and_Liabilit2

Regulatory Assets and Liabilities (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Regulatory Assets And Liabilities [Line Items]
DOE Claims	$2,161	$2,129
Maximum amortization period for deferred operation and maintenance costs	18 months
Regulatory assets represented past expenditures not earning return	218
Period expenditures expected to be recovered (years)	2 years
Virginia Electric and Power Company
Regulatory Assets And Liabilities [Line Items]
DOE Claims	1,773	1,638
Regulatory assets represented past expenditures not earning return	165
Dominion Gas Holdings, LLC
Regulatory Assets And Liabilities [Line Items]
DOE Claims	267	282
Regulatory assets represented past expenditures not earning return	45
DOE Claims
Regulatory Assets And Liabilities [Line Items]
DOE Claims	$5	$5

Regulatory_Assets_and_Liabilit3

Regulatory Assets and Liabilities (Regulatory Assets and Liabilities) (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Regulatory Assets And Liabilities [Line Items]
Deferred rate adjustment clause costs	$124	[1]	$89	[1]
Deferred cost of fuel used in electric generation	79	[2]	0	[2]
Deferred nuclear refueling outage costs	44	[3]	0	[3]
Unrecovered gas costs	36	[4]	50	[4]
Other	64		78
Regulatory assets-current	347		217
Unrecognized pension and other postretirement benefit costs	1,050	[5]	706	[5]
Deferred rate adjustment clause costs	250	[1]	287	[1]
Income taxes recoverable through future rates	133	[5]	155	[5]
Derivatives	101	[6]	16	[6]
Other	108		64
Regulatory assets-non-current	1,642		1,228
Total regulatory assets	1,989		1,445
PIPP, regulatory liabilities-current	71	[7]	76	[7]
Other	99		52
Regulatory liabilities-current	170	[8]	128	[8]
Provision for future cost of removal and AROs	1,072	[9]	1,028	[9]
Decommissioning trust	815	[10]	693	[10]
Deferred cost of fuel used in electric generation	6	[2]	90	[2]
Other	98		190
Regulatory liabilities-non-current	1,991		2,001
Total regulatory liabilities	2,161		2,129
Virginia Electric and Power Company
Regulatory Assets And Liabilities [Line Items]
Deferred rate adjustment clause costs	117	[1]	62	[1]
Deferred cost of fuel used in electric generation	79	[2]	0	[2]
Deferred nuclear refueling outage costs	44	[3]	0	[3]
Other	58		66
Regulatory assets-current	298		128
Deferred rate adjustment clause costs	179	[1]	227	[1]
Income taxes recoverable through future rates	100	[11]	124	[11]
Derivatives	101	[6]	16	[6]
Other	59		50
Regulatory assets-non-current	439		417
Total regulatory assets	737		545
Other	90		41
Regulatory liabilities-current	90		41
Provision for future cost of removal	852	[9]	807	[9]
Decommissioning trust	815	[10]	693	[10]
Deferred cost of fuel used in electric generation	6	[2]	90	[2]
Other	10		7
Regulatory liabilities-non-current	1,683		1,597
Total regulatory liabilities	1,773		1,638
Dominion Gas Holdings, LLC
Regulatory Assets And Liabilities [Line Items]
Deferred rate adjustment clause costs	7	[1]	27	[1]
Unrecovered gas costs	29	[4]	40	[4]
UEX Rider	0	[12]	11	[12]
Other	2		1
Regulatory assets-current	38		79
Unrecognized pension and other postretirement benefit costs	242	[5]	194	[5]
Deferred rate adjustment clause costs	71	[1]	59	[1]
Income taxes recoverable through future rates	24	[11]	24	[11]
Other	42		8
Regulatory assets-non-current	379		285
Total regulatory assets	417		364
PIPP, regulatory liabilities-current	71	[7]	76	[7]
Other	4		3
Regulatory liabilities-current	75		79
Provision for future cost of removal and AROs	172	[9]	177	[9]
Unrecognized pension and other postretirement benefit costs	0	[5]	18	[5]
Other	20		8
Regulatory liabilities-non-current	192		203
Total regulatory liabilities	$267		$282
[1]	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects for Virginia Power. Reflects deferrals of costs associated with certain current and prospective rider projects for Dominion Gas. See Note 13 for more information.
[2]	Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion's and Virginia Power’s generation operations. See Note 13 for more information. For 2014 and 2013, amount includes approximately $5 million related to DOE claims.
[3]	Legislation enacted in Virginia in April 2014 requires Virginia Power to defer operation and maintenance costs incurred in connection with the refueling of any nuclear-powered generating plant. These deferred costs will be amortized over the refueling cycle, not to exceed 18 months.
[4]	Reflects unrecovered gas costs at regulated gas operations, which are recovered through filings with the applicable regulatory authority.
[5]	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.
[6]	As discussed under Derivative Instruments in Note 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.
[7]	Under PIPP, eligible customers can make reduced payments 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. See Note 13 for more information.
[8]	Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.
[9]	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.
[10]	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.
[11]	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.
[12]	Represents East Ohio’s deferrals for the UEX Rider which are recovered through rates which are filed annually. Most of East Ohio’s bad debt expense is recovered either through the UEX Rider or the PIPP Rider. See Note 13 for more information.

Regulatory_Matters_Narrative_D

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

3 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

31-May-12

Mar. 31, 2010

Dec. 31, 2014

Sep. 30, 2014

31-May-14

Nov. 30, 2013

Aug. 31, 2013

Apr. 30, 2014

Jul. 31, 2013

Jan. 31, 2015

Mar. 31, 2015

Jul. 31, 2014

Jun. 30, 2014

Oct. 31, 2014

Aug. 31, 2014

Dec. 31, 2014

Dec. 31, 2012

Dec. 31, 2015

Feb. 28, 2014

Dec. 31, 2008

Nov. 30, 2014

Dec. 31, 2007

Feb. 27, 2015

Dec. 31, 2016

notice

motion

Part

MW

Program

customer

period

Regulatory Matters [Line Items]

Jurisdictional deferred fuel balance

$79,000,000

[1]

$0

[1]

$79,000,000

[1]

$79,000,000

[1]

Plant construction and other property additions (including nuclear fuel)

5,345,000,000

4,065,000,000

4,145,000,000

Charge recognized

374,000,000

0

0

Charge recognized for cumulative recovery of costs, after tax

191,000,000

193,000,000

Virginia Electric and Power Company

Regulatory Matters [Line Items]

Approved ROE

11.40%

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

Restoration costs net of tax

28,000,000

Jurisdictional deferred fuel balance

79,000,000

[1]

0

[1]

79,000,000

[1]

79,000,000

[1]

Plant construction and other property additions (including nuclear fuel)

2,911,000,000

2,394,000,000

2,082,000,000

Charge recognized

374,000,000

0

0

Charge recognized for cumulative recovery of costs, after tax

191,000,000

Virginia Electric and Power Company | Virginia Regulation

Regulatory Matters [Line Items]

Approved ROE

10.00%

10.90%

Earned ROE percentage

10.30%

10.25%

Basis points below authorized ROE

0.50%

Amount of deferred recovery costs authorized

23,000,000

Amount of revenue sufficiency

280,000,000

Charge related to Biennial Review Order

55,000,000

Restoration costs net of tax

37,000,000

Peer group floor ROE, percentage

9.89%

Market cost of equity, percentage

10.00%

Requested recovery amount for jurisdictional projected fuel expenses

1,900,000,000

Percentage recovery of total estimated jurisdictional deferred fuel balance

50.00%

Jurisdictional deferred fuel balance

268,000,000

Jurisdictional fuel balance recovered

134,000,000

Percentage of deferred fuel balance

50.00%

Revenue increase (decrease)

300,000,000

Number of motions filed for reconsideration

3

Number of appeals filed with Supreme Court

3

Number of notices withdrawn

2

Virginia Electric and Power Company | Virginia Regulation | Surry Switching Station Transmission Line

Regulatory Matters [Line Items]

KV Line

500

Virginia Electric and Power Company | Virginia Regulation | Surry Switching Station Transmission Line | Minimum

Regulatory Matters [Line Items]

Length of Transmission line

7

Virginia Electric and Power Company | Virginia Regulation | Transmission Line from Skiffes Creek Switching Station to Wheaton Substation

Regulatory Matters [Line Items]

Length of Transmission line

20

KV Line

230

Virginia Electric and Power Company | Virginia Regulation | North Anna

Regulatory Matters [Line Items]

Number of parts of amendment to COL application

2

Projected amount of capitalized costs recovered, percentage

70.00%

70.00%

Plant construction and other property additions (including nuclear fuel)

577,000,000

Virginia Electric and Power Company | Virginia Regulation | Legislation enacted | North Anna | Other operations and maintenance expense

Regulatory Matters [Line Items]

Charge recognized

374,000,000

Charge recognized for cumulative recovery of costs, after tax

248,000,000

Virginia Electric and Power Company | Virginia Regulation | Subsequent Event

Regulatory Matters [Line Items]

Generation capacity of solar development projects

20

Estimated project cost once constructed

47,000,000

Number of test periods

5

Virginia Electric and Power Company | Virginia Regulation | Subsequent Event | Maximum

Regulatory Matters [Line Items]

Generation capacity of solar development projects

500

Virginia Electric and Power Company | Virginia Regulation | Subsequent Event | Scenario, Forecast | Deferred Fuel Costs

Regulatory Matters [Line Items]

Write off of prior period deferred fuel costs

85,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider T1

Regulatory Matters [Line Items]

Revenue increase (decrease)

134,000,000

Approved revenue requirement

538,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider S

Regulatory Matters [Line Items]

Proposed revenue requirement

244,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider W

Regulatory Matters [Line Items]

Proposed revenue requirement

135,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider BW

Regulatory Matters [Line Items]

Proposed revenue requirement

111,000,000

Virginia Electric and Power Company | Virginia Regulation | Riders C1A and C2A

Regulatory Matters [Line Items]

Proposed revenue requirement

47,000,000

Number of new energy efficiency programs

3

Period for cost cap

5 years

Cost cap amount

106,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider R

Regulatory Matters [Line Items]

Proposed revenue requirement

84,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider U

Regulatory Matters [Line Items]

Proposed revenue requirement

28,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider B

Regulatory Matters [Line Items]

Proposed revenue requirement

13,000,000

Virginia Electric and Power Company | North Carolina Regulation

Regulatory Matters [Line Items]

Approved ROE

10.20%

10.20%

Revenue increase (decrease)

36,000,000

Increase (decrease) in annual base fuel revenues

17,000,000

-14,000,000

Total base revenues

22,000,000

Virginia Electric and Power Company | North Carolina Regulation | Scenario, Forecast

Regulatory Matters [Line Items]

Percentage of deferred fuel balance

50.00%

Virginia Electric and Power Company | North Carolina Regulation | Scenario, Forecast | Maximum

Regulatory Matters [Line Items]

Cost cap amount

17,000,000

East Ohio | Ohio Regulation

Regulatory Matters [Line Items]

Plant construction and other property additions (including nuclear fuel)

110,000,000

East Ohio | Ohio Regulation | PIR Program

Regulatory Matters [Line Items]

Percentage replacement of pipeline system

25.00%

Total plant investment

164,000,000

Cumulative gross plant investment

674,000,000

Approved revenue requirement

89,000,000

East Ohio | Ohio Regulation | AMR Program

Regulatory Matters [Line Items]

Revenue increase (decrease)

3,000,000

Approved revenue requirement

8,000,000

Proposed revenue requirement

8,000,000

Number of customers with automated meter reading technology

1,200,000

East Ohio | Ohio Regulation | PIPP Plus Program

Regulatory Matters [Line Items]

Refund of overrecovery of accumulated arrearages

82,000,000

Recovery of projected deferred program costs

96,000,000

East Ohio | Ohio Regulation | UEX Rider

Regulatory Matters [Line Items]

Elimination of over-recovered balance of accumulated bad debt expense

8,000,000

Prospective bad debt expense recovered

25,000,000

East Ohio | Ohio Regulation | Subsequent Event | PIR Program

Regulatory Matters [Line Items]

Total plant investment

155,000,000

Cumulative gross plant investment

829,000,000

Approved revenue requirement

108,000,000

DTI

Regulatory Matters [Line Items]

Amount of refunds provided

$10,000,000

[1]

Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion's and Virginia Power’s generation operations. See Note 13 for more information. For 2014 and 2013, amount includes approximately $5 million related to DOE claims.

Asset_Retirement_Obligations_N

Asset Retirement Obligations (Narrative) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligations [Line Items]
Fair value, primarily of equity and debt securities	$4,200,000,000	$3,900,000,000
Nuclear decommissioning trust funds	4,196,000,000	3,903,000,000
Virginia Electric and Power Company
Asset Retirement Obligations [Line Items]
Nuclear decommissioning trust funds	$1,930,000,000	$1,765,000,000

Asset_Retirement_Obligations_C

Asset Retirement Obligations (Changes to AROs) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance	$1,578	[1]	$1,705	[1]
Obligations incurred during the period	40		13
Obligations settled during the period	-82		-68
Revisions in estimated cash flows	102	[2]	-129	[3]
Accretion	81		86
Other	-5		-29
AROs , Ending balance	1,714	[1]	1,578	[1]
Other current liabilities	81		94		64
Virginia Electric and Power Company
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance	689		705
Obligations incurred during the period	28		2
Obligations settled during the period	-1		-2
Revisions in estimated cash flows	108	[2]	-52	[3]
Accretion	37		38
Other	-6		-2
AROs , Ending balance	855	[4]	689
Virginia Electric and Power Company | Other Current Liabilities
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation	7
Dominion Gas Holdings, LLC
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance	137	[5],[6]	133
Obligations incurred during the period	2		8
Obligations settled during the period	-8		-13
Accretion	8		8
Other	8		1
AROs , Ending balance	147	[5],[6]	137	[5],[6]
Dominion Gas Holdings, LLC | Other Current Liabilities
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation	7		2
Dominion Gas Holdings, LLC | Other Deferred Credits and Other Liabilities
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation	$140		$135
[1]	Includes $64 million, $94 million and $81 million reported in other current liabilities at December 31, 2012, 2013, and 2014, respectively.
[2]	Relates primarily to a shift of the delayed planned date on which the DOE is expected to begin accepting spent nuclear fuel.
[3]	Primarily reflects lower anticipated nuclear decommissioning costs.
[4]	Includes $7 million reported in other current liabilities at December 31, 2014.
[5]	Includes $2 million and $7 million reported in other current liabilities at December 31, 2013 and 2014, respectively.
[6]	Includes $135 million and $140 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2013 and 2014, respectively.

Variable_Interest_Entities_Nar

Variable Interest Entities (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2013	Sep. 30, 2014
Variable Interest Entity [Line Items]
Acquisition of Juniper noncontrolling interest in Fairless	$0	$923	$0
Virginia Electric and Power Company
Variable Interest Entity [Line Items]
Number of non utility generators	5
Aggregate generation capacity from long-term power and capacity contracts (MW)	870
Remaining purchase commitments	639
Payment for electric capacity	223	217	214
Payment for electric energy	138	98	83
Shared services purchased	335	331	328
Dominion Gas Holdings, LLC
Variable Interest Entity [Line Items]
Shared services purchased	106	115	107
Juniper
Variable Interest Entity [Line Items]
Acquisition of Juniper noncontrolling interest in Fairless				$923
Variable Interest Entity, Not Primary Beneficiary | Gas Distribution | Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline
Variable Interest Entity [Line Items]
Initial membership interest percentage					45.00%

ShortTerm_Debt_And_Credit_Agre2

Short-Term Debt And Credit Agreements (Commercial Paper, Bank Loans, and Letters of Credit Outstanding, as well as Capacity Available Under Credit Facilities (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013		31-May-14	1-May-14	Jul. 31, 2014	Jul. 01, 2014	Jan. 31, 2015
	Facility
Short term Debt [Line Items]
Facility Limit	$4,500,000,000		$3,500,000,000
Outstanding Commercial Paper	2,775,000,000	[1]	1,927,000,000	[1]
Outstanding Letters of Credit	48,000,000		11,000,000
Facility Capacity Available	1,677,000,000		1,562,000,000
Weighted-average interest rates of the outstanding commercial paper	0.38%		0.33%
Number of joint revolving credit facilities	2
Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit	1,500,000,000		1,250,000,000
Outstanding Commercial Paper	1,361,000,000	[2]	842,000,000	[2]
Outstanding Letters of Credit	0		1,000,000
Facility Capacity Available	139,000,000		407,000,000
Weighted-average interest rates of the outstanding commercial paper	0.36%		0.33%
Credit facility	120,000,000
Credit Facility 4 Billion
Short term Debt [Line Items]
Facility Limit	4,000,000,000	[3]	3,000,000,000	[3]	4,000,000,000	3,000,000,000
Outstanding Commercial Paper	2,664,000,000	[3]	1,927,000,000	[3]
Outstanding Letters of Credit	0	[3]	0	[3]
Facility Capacity Available	1,336,000,000	[3]	1,073,000,000	[3]
Credit facility, to support letters of credit	1,500,000,000
Credit Facility 4 Billion | Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit	1,250,000,000	[4]	1,000,000,000	[4]			1,250,000,000	1,000,000,000
Outstanding Commercial Paper	1,250,000,000	[4]	842,000,000	[4]
Outstanding Letters of Credit	0	[4]	0	[4]
Facility Capacity Available	0	[4]	158,000,000	[4]
Credit facility, to support letters of credit	1,500,000,000
Credit Facility 4 Billion | Virginia Electric and Power Company | Subsequent Event
Short term Debt [Line Items]
Facility Limit									1,500,000,000
Credit Facility 4 Billion | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Facility Limit	1,000,000,000
Credit facility, to support letters of credit	500,000,000
Credit Facility 500 million
Short term Debt [Line Items]
Facility Limit	500,000,000	[5]	500,000,000	[5]
Outstanding Commercial Paper	111,000,000	[5]	0	[5]
Outstanding Letters of Credit	48,000,000	[5]	11,000,000	[5]
Facility Capacity Available	341,000,000	[5]	489,000,000	[5]
Credit Facility 500 million | Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit	250,000,000	[6]	250,000,000	[6]
Outstanding Commercial Paper	111,000,000	[6]	0	[6]
Outstanding Letters of Credit	0	[6]	1,000,000	[6]
Facility Capacity Available	139,000,000	[6]	249,000,000	[6]
Credit Facility 500 million | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Credit facility, to support letters of credit	0
Tax-Exempt Financings | Virginia Electric and Power Company
Short term Debt [Line Items]
Variable rate tax-exempt financings	$119,000,000
[1]	The weighted-average interest rates of the outstanding commercial paper supported by Dominion's credit facilities were 0.38% and 0.33% at December 31, 2014 and 2013, respectively.
[2]	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.36% and 0.33% at December 31, 2014 and 2013, respectively.
[3]	In May 2014, this credit facility was amended and restated. The facility limit was increased from $3 billion to $4 billion and the maturity date was extended from September 2018 to April 2019. 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.
[4]	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. 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. In July 2014, Virginia Power increased its sub-limit from $1.0 billion to $1.25 billion. In January 2015, Virginia Power increased its sub-limit on this facility from $1.25 billion to $1.5 billion
[5]	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
[6]	In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. 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.

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

Jan. 31, 2013

Sep. 30, 2011

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Jul. 31, 2017

Jul. 31, 2016

Apr. 30, 2016

Jul. 31, 2014

Jun. 30, 2013

Feb. 28, 2012

Dec. 31, 2014

Nov. 30, 2014

Oct. 01, 2024

Jun. 30, 2014

Jul. 01, 2014

Jul. 01, 2006

Jun. 30, 2006

Sep. 30, 2006

Oct. 31, 2014

Jun. 30, 2009

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$23,200,000,000

$23,200,000,000

Make-whole premium amount

284,000,000

0

0

Shares issued in excess of principal amounts related to converted securities

28,000,000

Noncontrolling interest, ownership percentage by parent

100.00%

100.00%

Beneficial ownership percentage

97.00%

Beneficial ownership interest

3.00%

Percentage in capital trust assets

100.00%

Redemption of units of Dominion Resources Capital Trust I capital securities

250,000

Dominion Resources Capital Trust I capital securities

250,000,000

Rate of Dominion Resources Capital Trust I capital securities

7.83%

Redemption price per capital security

$1,019.58

Deferral

10 years

Period for consideration of proceeds (days)

180 days

365 days

Interest in RSN issued by Dominion (percentage)

5.00%

5.00%

Shares reserved and available for issuance

7,000,000

7,000,000

Dominion Gas Holdings, LLC

Debt Instrument [Line Items]

Aggregate outstanding principal amount

2,600,000,000

2,600,000,000

Scenario, Forecast | Minimum

Debt Instrument [Line Items]

Shares to be issued under purchase contracts

11,500,000

8,400,000

8,400,000

Scenario, Forecast | Maximum

Debt Instrument [Line Items]

Shares to be issued under purchase contracts

14,300,000

9,900,000

9,900,000

Common Stock

Debt Instrument [Line Items]

Purchase price to be paid under stock purchase contracts

$50

$50

Shares reserved and available for issuance

40,300,000

40,300,000

Capital Unit, Class A

Debt Instrument [Line Items]

Issuance of Dominion Midstream common units, net of offering costs

1,000,000,000

550,000,000

Payment rate on Equity Units

6.13%

6.38%

Capital Unit, Class B

Debt Instrument [Line Items]

Issuance of Dominion Midstream common units, net of offering costs

550,000,000

Payment rate on Equity Units

6.00%

June 2006 hybrids

Debt Instrument [Line Items]

Interest rate (percentage)

2.83%

7.50%

Junior subordinated notes

300,000,000

September 2006 hybrids

Debt Instrument [Line Items]

Interest rate (percentage)

2.30%

Junior subordinated notes

500,000,000

Tender offer to purchase additional hybrids

150,000,000

Purchased and cancelled of junior subordinated notes

88,000,000

June 2009 hybrids

Debt Instrument [Line Items]

Interest rate (percentage)

8.38%

Aggregate redemption price paid

685,000,000

Junior subordinated notes

685,000,000

7.83% Debentures due 12/1/2027

Debt Instrument [Line Items]

Interest rate (percentage)

7.83%

Junior subordinated notes

258,000,000

Convertible Debt

Debt Instrument [Line Items]

Outstanding contingent convertible senior notes

0

0

22,000,000

Average trading price principal amount of the senior notes

120.00%

Minimum consecutive trading days

20 days

Maximum consecutive trading days

30 days

Amount of notes converted by holders

21,000,000

Shares issued in excess of principal amounts related to converted securities

23,000,000

26,000,000

Unsecured Junior Subordinated Notes Payable to Affiliated Trusts

Debt Instrument [Line Items]

Aggregate outstanding principal amount

10,000,000

10,000,000

Interest charges

1,000,000

1,000,000

21,000,000

Unsecured Junior Subordinated Notes Payable to Affiliated Trusts | Enhanced Junior Subordinated Notes, 5.75%

Debt Instrument [Line Items]

Interest rate (percentage)

5.75%

Principal amount of notes

685,000,000

Unsecured Junior Subordinated Notes Payable to Affiliated Trusts | LIBOR | Scenario, Forecast | Enhanced Junior Subordinated Notes, 5.75%

Debt Instrument [Line Items]

Spread on variable rate

3.06%

Senior Notes

Debt Instrument [Line Items]

Aggregate outstanding principal amount

1,900,000,000

1,900,000,000

Aggregate redemption price paid

2,200,000,000

2,200,000,000

Make-whole premium amount

263,000,000

Interest charges

284,000,000

Senior Notes | Dominion Gas Holdings, LLC

Debt Instrument [Line Items]

Principal amount offered in exchange

$1,200,000,000

Senior Notes | Series C 2005 Senior Notes Due 2015

Debt Instrument [Line Items]

Interest rate (percentage)

5.15%

5.15%

Senior Notes | Series A 2004 Senior Notes Due 2016

Debt Instrument [Line Items]

Interest rate (percentage)

5.20%

5.20%

Senior Notes | Series A 2006 Senior Notes Due 2016

Debt Instrument [Line Items]

Interest rate (percentage)

5.60%

5.60%

Senior Notes | Series A 2007 Senior Notes Due 2017

Debt Instrument [Line Items]

Interest rate (percentage)

6.00%

6.00%

Senior Notes | Series D 2008 Senior Notes Due 2019

Debt Instrument [Line Items]

Interest rate (percentage)

8.88%

8.88%

LongTerm_Debt_Total_Long_Term_

Long-Term Debt (Total Long Term Debt) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Debt Instrument [Line Items]
2013 Weighted- average Coupon	3.30%	[1],[2]
Total principal, including VIE	$23,200,000,000		$20,842,000,000
Securities due within one year, including VIE	-1,375,000,000	[2]	-1,519,000,000	[2]
Unamortized discount and premium, net	-39,000,000		-48,000,000
Total long term debt, including VIE	21,805,000,000		19,330,000,000
Fair value hedge valuation	19,000,000	[3]	55,000,000	[3]
Unamortized premium and discount			4,000,000		14,000,000
5.25% Senior Notes Due 2033
Debt Instrument [Line Items]
Senior notes	510,000,000
RSN Annual Interest Rate	5.25%
Long term debt maturity date	2033
Redemption percentage of principal and accrued interest	100.00%
Senior Notes | Variable rates, due 2014 and 2015
Debt Instrument [Line Items]
2013 Weighted- average Coupon	0.36%	[1]
Total principal, including VIE	400,000,000		400,000,000
Senior Notes | 1.25% to 8.875%, due 2014 to 2019
Debt Instrument [Line Items]
Interest rate, minimum	1.25%
Interest rate, maximum	8.88%
2013 Weighted- average Coupon	3.17%	[1]
Total principal, including VIE	3,150,000,000		4,391,000,000
Senior Notes | 2.75% to 7.0%, due 2022 to 2044
Debt Instrument [Line Items]
Interest rate, minimum	2.75%
Interest rate, maximum	7.00%
2013 Weighted- average Coupon	4.93%	[1],[4]
Total principal, including VIE	4,449,000,000	[4]	3,499,000,000	[4]
Senior Notes | Unsecured Convertible Senior Notes, 2.125%, due 2023
Debt Instrument [Line Items]
Total principal, including VIE	0		43,000,000
RSN Annual Interest Rate	2.13%
Senior Notes | 5.0% due 2014
Debt Instrument [Line Items]
Total principal, including VIE	0	[5]	600,000,000	[5]
RSN Annual Interest Rate	5.00%
Senior Notes | 6.8% and 6.875%, due 2026 and 2027
Debt Instrument [Line Items]
Interest rate, minimum	6.80%
Interest rate, maximum	6.88%
2013 Weighted- average Coupon	6.81%	[1],[5]
Total principal, including VIE	89,000,000	[5]	89,000,000	[5]
Tax-Exempt Financings | Tax-Exempt Financing, 2.375%, due 2033
Debt Instrument [Line Items]
2013 Weighted- average Coupon	2.38%	[1]
Total principal, including VIE	27,000,000		27,000,000
RSN Annual Interest Rate	2.38%
Tax-Exempt Financings | Variable rate, due 2041
Debt Instrument [Line Items]
2013 Weighted- average Coupon	1.10%	[1]
Total principal, including VIE	75,000,000		75,000,000
Junior Subordinated Notes | Unsecured Junior Subordinated Notes Payable to Affiliated Trust, 8.4%, due 2031
Debt Instrument [Line Items]
2013 Weighted- average Coupon	8.40%	[1]
Total principal, including VIE	10,000,000		10,000,000
RSN Annual Interest Rate	8.40%
Junior Subordinated Notes | 5.75% to 8.375%, due 2054 to 2066
Debt Instrument [Line Items]
Interest rate, minimum	5.75%
Interest rate, maximum	8.38%
2013 Weighted- average Coupon	6.28%	[1]
Total principal, including VIE	985,000,000		985,000,000
Junior Subordinated Notes | Enhanced Junior Subordinated Notes, variable rate, due 2066
Debt Instrument [Line Items]
2013 Weighted- average Coupon	2.54%	[1]
Total principal, including VIE	380,000,000		380,000,000
Remarketable Subordinated Notes | Remarketable Subordinated Notes, 1.07% to 1.50%, due 2019 to 2021
Debt Instrument [Line Items]
Interest rate, minimum	1.07%
Interest rate, maximum	1.50%
2013 Weighted- average Coupon	1.30%	[1]
Total principal, including VIE	2,100,000,000		1,100,000,000
Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Total principal, including VIE	2,600,000,000		1,200,000,000
Unamortized discount and premium, net	-6,000,000		-2,000,000
Total long term debt, including VIE	2,594,000,000		1,198,000,000
Dominion Gas Holdings, LLC | Senior Notes | 1.05% and 2.5%, due 2016 and 2019
Debt Instrument [Line Items]
Interest rate, minimum	1.05%
Interest rate, maximum	2.50%
2013 Weighted- average Coupon	1.82%	[1]
Total principal, including VIE	850,000,000		400,000,000
Dominion Gas Holdings, LLC | Senior Notes | 3.55% to 4.8%, due 2023 to 2044
Debt Instrument [Line Items]
Interest rate, minimum	3.55%
Interest rate, maximum	4.80%
2013 Weighted- average Coupon	4.15%	[1]
Total principal, including VIE	1,750,000,000		800,000,000
Virginia Electric and Power Company
Debt Instrument [Line Items]
2013 Weighted- average Coupon	5.39%	[1]
Total principal, including VIE	8,935,000,000		8,043,000,000
Securities due within one year, including VIE	-211,000,000		-58,000,000
Unamortized discount and premium, net	2,000,000		-11,000,000
Total long term debt, including VIE	8,726,000,000		7,974,000,000
Virginia Electric and Power Company | Line of Credit
Debt Instrument [Line Items]
Credit facility, to support letters of credit	120,000,000
Virginia Electric and Power Company | Senior Notes | 1.2% to 8.625%, due 2015 to 2019
Debt Instrument [Line Items]
Interest rate, minimum	1.20%
Interest rate, maximum	8.63%
2013 Weighted- average Coupon	5.06%	[1]
Total principal, including VIE	2,471,000,000		2,488,000,000
Virginia Electric and Power Company | Senior Notes | 2.75% to 8.875%, due 2022 to 2044
Debt Instrument [Line Items]
Interest rate, minimum	2.75%
Interest rate, maximum	8.88%
2013 Weighted- average Coupon	5.07%	[1]
Total principal, including VIE	5,592,000,000		4,643,000,000
Virginia Electric and Power Company | Tax-Exempt Financings | Variable rates, due 2016 to 2041
Debt Instrument [Line Items]
2013 Weighted- average Coupon	0.93%	[1],[6]
Total principal, including VIE	606,000,000	[6]	606,000,000	[6]
Virginia Electric and Power Company | Tax-Exempt Financings | 0.70% to 5.6%, due 2022 to 2040
Debt Instrument [Line Items]
Interest rate, minimum	0.70%
Interest rate, maximum	5.60%
2013 Weighted- average Coupon	2.86%	[1],[6]
Total principal, including VIE	$266,000,000	[6]	$306,000,000	[6]
[1]	Represents weighted-average coupon rates for debt outstanding as of December 31, 2014.
[2]	Includes $4 million fair value hedge valuation in 2014 and $14 million of fair value hedge valuation in 2013.
[3]	Represents the valuation of certain fair value hedges associated with Dominion's fixed rate debt.
[4]	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015. As a result, at December 31, 2014, the notes were included in Securities due within one year in the Consolidated Balance Sheets.
[5]	Represents debt assumed by Dominion from the merger of its former CNG subsidiary.
[6]	These financings relate to certain pollution control equipment at Virginia Power's generating facilities. Certain variable rate tax-exempt financings are supported by a $120 million credit facility that terminates in April 2019.

LongTerm_Debt_Based_on_Stated_

Long-Term Debt (Based on Stated Maturity Dates Rather than Early Redemption Dates that Could be Elected by Instrument Holders) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
Debt Instrument [Line Items]
2014	$861,000,000
2015	1,327,000,000
2016	1,429,000,000
2017	1,350,000,000
2018	2,550,000,000
Thereafter	15,683,000,000
Total	23,200,000,000
5.25% Senior Notes Due 2033
Debt Instrument [Line Items]
Senior notes	510,000,000
Interest rate (percentage)	5.25%
Redemption percentage of principal and accrued interest	100.00%
Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
2014	0
2015	400,000,000
2016	0
2017	0
2018	450,000,000
Thereafter	1,750,000,000
Total	2,600,000,000
Virginia Electric and Power Company
Debt Instrument [Line Items]
2014	211,000,000
2015	476,000,000
2016	679,000,000
2017	850,000,000
2018	350,000,000
Thereafter	6,369,000,000
Total	8,935,000,000
2015
Debt Instrument [Line Items]
Weighted-average Coupon	2.14%
2015 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon	5.39%
2016
Debt Instrument [Line Items]
Weighted-average Coupon	2.86%
2016 | Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Weighted-average Coupon	1.05%
2016 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon	5.24%
2017
Debt Instrument [Line Items]
Weighted-average Coupon	3.27%
2017 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon	5.43%
2018
Debt Instrument [Line Items]
Weighted-average Coupon	4.99%
2018 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon	4.17%
2019
Debt Instrument [Line Items]
Weighted-average Coupon	3.09%
2019 | Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Weighted-average Coupon	2.50%
2019 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon	5.00%
Thereafter
Debt Instrument [Line Items]
Weighted-average Coupon	4.39%
Thereafter | Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Weighted-average Coupon	4.15%
Thereafter | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon	4.64%
Unsecured Senior Notes(1)
Debt Instrument [Line Items]
2014	861,000,000	[1]
2015	1,308,000,000	[1]
2016	1,354,000,000	[1]
2017	1,350,000,000	[1]
2018	2,000,000,000	[1]
Thereafter	11,878,000,000	[1]
Total	18,751,000,000	[1]
Tax-Exempt Financings
Debt Instrument [Line Items]
2014	0
2015	19,000,000
2016	75,000,000
2017	0
2018	0
Thereafter	880,000,000
Total	974,000,000
Unsecured Junior Subordinated Notes Payable to Affiliated Trusts
Debt Instrument [Line Items]
2014	0
2015	0
2016	0
2017	0
2018	0
Thereafter	10,000,000
Total	10,000,000
Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
2014	0
2015	0
2016	0
2017	0
2018	0
Thereafter	1,365,000,000
Total	1,365,000,000
Remarketable Subordinated Notes
Debt Instrument [Line Items]
2014	0
2015	0
2016	0
2017	0
2018	550,000,000
Thereafter	1,550,000,000
Total	$2,100,000,000
[1]	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015. As a result, at December 31, 2014, the notes were included in Securities due within one year in the Consolidated Balance Sheets.

LongTerm_Debt_Long_Term_Debt_S

Long-Term Debt Long Term Debt (Schedule of Equity Units) (Details) (USD $)	12 Months Ended				0 Months Ended
Share data in Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Jul. 01, 2014		Jun. 07, 2013
Capital Unit [Line Items]
Stock Purchase Contract Liability	$216,000,000	[1]	$139,000,000	[1]
Total payments	66,000,000		17,000,000
Capital Unit, Class A
Capital Unit [Line Items]
Units Issued					20		11
Total Net Proceeds					982,000,000		533,500,000
Stock Purchase Contract Annual Rate					4.88%		5.06%
Stock Purchase Contract Liability					142,800,000	[1]	76,700,000	[1]
Capital Unit, Class A | Remarketable Subordinated Notes
Capital Unit [Line Items]
Total Long-term Debt					1,000,000,000		550,000,000
RSN Annual Interest Rate					1.50%		1.07%
Capital Unit, Class B
Capital Unit [Line Items]
Units Issued							11
Total Net Proceeds							553,500,000
Stock Purchase Contract Annual Rate							4.82%
Stock Purchase Contract Liability							79,300,000	[1]
Capital Unit, Class B | Remarketable Subordinated Notes
Capital Unit [Line Items]
Total Long-term Debt							$550,000,000
RSN Annual Interest Rate							1.18%
[1]	Payments of $66 million and $17 million were made in 2014 and 2013, respectively. The stock purchase contract liability was $216 million and $139 million at December 31, 2014 and 2013, respectively.

Preferred_Stock_Narrative_Deta

Preferred Stock (Narrative) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Class of Stock [Line Items]
Preferred stock shares authorized	20,000,000
Preferred stock shares issued	0	0
Preferred stock shares outstanding	0	0
Virginia Electric and Power Company
Class of Stock [Line Items]
Preferred stock shares authorized	10,000,000
Preferred stock shares issued	2,590,000	2,590,000
Preferred stock shares outstanding	2,590,000	2,590,000
Amount each share is entitled to receive	100

Preferred_Stock_Preferred_Stoc

Preferred Stock Preferred Stock (Schedule of Preferred Stock) (Details) (Virginia Electric and Power Company, USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014
Class of Stock [Line Items]
Total Shares	2,590
Redemption Price Per Share	$100
Dividend rate (percentage)	6.12%
$5.00
Class of Stock [Line Items]
Dividend	$5
Total Shares	107
Redemption Price Per Share	$112.50	[1]
$4.04
Class of Stock [Line Items]
Dividend	$4.04
Total Shares	13
Redemption Price Per Share	$102.27	[1]
$4.20
Class of Stock [Line Items]
Dividend	$4.20
Total Shares	15
Redemption Price Per Share	$102.50	[1]
$4.12
Class of Stock [Line Items]
Dividend	$4.12
Total Shares	32
Redemption Price Per Share	$103.73	[1]
$4.80
Class of Stock [Line Items]
Dividend	$4.80
Total Shares	73
Redemption Price Per Share	$101	[1]
$7.05
Class of Stock [Line Items]
Dividend	$7.05
Total Shares	500
Redemption Price Per Share	$100	[1]
$6.98
Class of Stock [Line Items]
Dividend	$6.98
Total Shares	600
Redemption Price Per Share	$100	[1]
Flex Money Market Preferred 12/02, Series A
Class of Stock [Line Items]
Total Shares	1,250
Redemption Price Per Share	$100	[2]
[1]	As part of Dominion's Liability Management Exercise, in September 2014, Virginia Power provided irrevocable notice to redeem all shares outstanding for each series of preferred stock. In October 2014, the stock was redeemed at the applicable price per share plus accumulated and unpaid dividends.
[2]	In February 2014, Virginia Power provided irrevocable notice to redeem the stock. In March 2014, the stock was redeemed at the applicable price per share plus accumulated and unpaid dividends at a rate reset in March 2011 of 6.12%. Dividends ceased accumulating on the stock upon payment of the redemption price, thus the rate was not reset in March 2014.

Equity_Narrative_Details

Equity (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

1 Months Ended

2 Months Ended

1 Months Ended

0 Months Ended

Dec. 31, 2014

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2007

Feb. 28, 2013

Feb. 28, 2011

Jan. 31, 2014

Dec. 31, 2013

Feb. 27, 2015

Jan. 31, 2015

Sep. 30, 2013

Agreement

agent

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Cash proceeds

$205,000,000

$278,000,000

$265,000,000

Number of sales agency agreements

4

Expected issuance of common stock in 2012 through employee savings plans, direct stock purchase and dividend reinvestment plans, and other employee and director benefit plans

500,000,000

Net fees and commissions paid

2,000,000

Shares reserved and available for issuance

7,000,000

7,000,000

Compensation cost related to stock-based compensation

39,000,000

31,000,000

25,000,000

Tax benefit from stock awards and stock options exercised

14,000,000

11,000,000

8,000,000

Tax benefits from the vesting of restricted stock awards

1,000,000

1,000,000

10,000,000

Dominion Direct, Employee Stock Awards, Employee Savings Plans, Director Stock Compensation Plans, and Contingent Convertible Senior Notes

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Shares reserved and available for issuance

56,000,000

56,000,000

Stock-Based Awards

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Maximum term of stock based awards

8 years

Shares were available for future grants

31,000,000

31,000,000

Restricted Stock

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Vesting period

3 years

Unrecognized compensation cost related to nonvested awards

27,000,000

27,000,000

Expected weighted-average period recognized for the unrecognized compensation cost

1 year 9 months 6 days

Fair value of restricted stock awards that vested

19,000,000

20,000,000

30,000,000

Goal-Based Stock

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Vesting period

3 years

Number of performance metrics

2

Performance metrics period

2 years

Shares issued minimum percentage

0.00%

Shares issued maximum percentage

200.00%

Targeted shares expected to be issued

17,000

17,000

Cash-Based Performance Grant

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Cash-based performance grants minimum

0.00%

Cash-based performance grants maximum

200.00%

February 2011 Awards

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Number of performance metrics

2

Cash based performance grant actual payout

2,000,000

6,000,000

Cash-based performance grants

8,000,000

February 2012 Awards

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Number of performance metrics

2

Cash based performance grant actual payout

14,000,000

12,000,000

8,000,000

Cash based performance grants, total expected award

21,000,000

Cash based performance grant liability accrued

7,000,000

February 2013 Awards

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Number of performance metrics

2

Cash-based performance grants

13,000,000

Cash based performance grant liability accrued

3,000,000

Subsequent Event

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Cash proceeds

207,000,000

Number of sales agents

1

Stock issued by sales agents

2,700,000

Net fees and commissions paid

2,000,000

Shares reserved and available for issuance

291,000,000

Subsequent Event | Goal-Based Stock

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Number of shares converted to one class to another

7,000

Dominion Gas Holdings, LLC

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Percentage of limited liability membership interests

100.00%

Various Programs

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Common stock shares issued

3,800,000

3,800,000

Dominion Direct, employee savings plans

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Common stock shares issued

2,900,000

2,900,000

Cash proceeds

$205,000,000

Equity_Accumulated_Other_Compr

Equity (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net unrealized losses on derivatives-hedging activities, net of tax	($178)	($288)
Net unrealized gains on nuclear decommissioning trust funds, net of tax	548	474
Net unrecognized pension and other postretirement benefit costs, net of tax	-782	-510
Other comprehensive loss from equity method investees, net of tax	-4	0
Total AOCI	-416	-324	-877
Net unrealized gains on derivatives-hedging activities, tax	116	196
Net unrealized gains on nuclear decommissioning trust funds, tax	-333	-307
Net unrecognized pension and other postretirement benefit costs, tax	530	365
Other comprehensive loss from equity method investees, tax	3	0
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net unrealized losses on derivatives-hedging activities, net of tax	-7	0
Net unrealized gains on nuclear decommissioning trust funds, net of tax	57	48
Total AOCI	50	48	25
Net unrealized gains on derivatives-hedging activities, tax	4	0
Net unrecognized pension and other postretirement benefit costs, tax	-35	-30
Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net unrealized losses on derivatives-hedging activities, net of tax	-20	3
Net unrealized gains on nuclear decommissioning trust funds, net of tax	-66	-61
Total AOCI	-86	-58	-140
Net unrealized gains on derivatives-hedging activities, tax	11	-1
Net unrecognized pension and other postretirement benefit costs, tax	$46	$43

Equity_Schedule_of_Components_

Equity (Schedule of Components of Accumulated Other Comprehensive Income) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	($324)		($877)
Other comprehensive income before reclassifications: gains (losses)	-164		476
Amounts reclassified from accumulated other comprehensive income: (gains) losses	72	[1]	77	[1]
Other comprehensive income (loss)	-92		553		-267
Ending balance	-416		-324		-877
Deferred gains and losses on derivatives-hedging activities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	-288		-122
Other comprehensive income before reclassifications: gains (losses)	17		-243
Amounts reclassified from accumulated other comprehensive income: (gains) losses	93	[1]	77	[1]
Other comprehensive income (loss)	110		-166
Ending balance	-178		-288
Unrealized gains and losses on investment securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	474		326
Other comprehensive income before reclassifications: gains (losses)	128		203
Amounts reclassified from accumulated other comprehensive income: (gains) losses	-54	[1]	-55	[1]
Other comprehensive income (loss)	74		148
Ending balance	548		474
Unrecognized pension and other postretirement benefit costs
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	-510		-1,081
Other comprehensive income before reclassifications: gains (losses)	-305		516
Amounts reclassified from accumulated other comprehensive income: (gains) losses	33	[1]	55	[1]
Other comprehensive income (loss)	-272		571
Ending balance	-782		-510
Other comprehensive loss from equity method investees
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	0		0
Other comprehensive income before reclassifications: gains (losses)	-4		0
Amounts reclassified from accumulated other comprehensive income: (gains) losses	0	[1]	0	[1]
Other comprehensive income (loss)	-4		0
Ending balance	-4		0
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	48		25
Other comprehensive income before reclassifications: gains (losses)	11		26
Amounts reclassified from accumulated other comprehensive income: (gains) losses	-9	[1]	-3	[1]
Other comprehensive income (loss)	2		23		6
Ending balance	50		48		25
Virginia Electric and Power Company | Deferred gains and losses on derivatives-hedging activities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	0		-6
Other comprehensive income before reclassifications: gains (losses)	-4		6
Amounts reclassified from accumulated other comprehensive income: (gains) losses	-3	[1]	0	[1]
Other comprehensive income (loss)	-7		6
Ending balance	-7		0
Virginia Electric and Power Company | Unrealized gains and losses on investment securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	48		31
Other comprehensive income before reclassifications: gains (losses)	15		20
Amounts reclassified from accumulated other comprehensive income: (gains) losses	-6	[1]	-3	[1]
Other comprehensive income (loss)	9		17
Ending balance	57		48
Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	-58		-140
Other comprehensive income before reclassifications: gains (losses)	-41		65
Amounts reclassified from accumulated other comprehensive income: (gains) losses	13	[1]	17	[1]
Other comprehensive income (loss)	-28		82		31
Ending balance	-86		-58		-140
Dominion Gas Holdings, LLC | Deferred gains and losses on derivatives-hedging activities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	3		-47
Other comprehensive income before reclassifications: gains (losses)	-31		39
Amounts reclassified from accumulated other comprehensive income: (gains) losses	8	[1]	11	[1]
Other comprehensive income (loss)	-23		50
Ending balance	-20		3
Dominion Gas Holdings, LLC | Unrealized gains and losses on investment securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	-61		-93
Other comprehensive income before reclassifications: gains (losses)	-10		26
Amounts reclassified from accumulated other comprehensive income: (gains) losses	5	[1]	6	[1]
Other comprehensive income (loss)	-5		32
Ending balance	($66)		($61)
[1]	See table below for details about these reclassifications.

Equity_Schedule_of_Reclassific

Equity (Schedule of Reclassifications out of Accumulated Other Comprehensive Income) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operating Revenue	$2,943	$3,050	$2,813	$3,630	$3,185	$3,432	$2,980	$3,523	$12,436		$13,120		$12,835
Purchased gas									1,355		1,331		1,177
Electric fuel and other energy-related purchases									3,400		3,885		3,645
Interest and related charges									1,193		877		816
Income from continuing operations including noncontrolling interests before income taxes									1,778		2,704		2,265
Income tax expense									-452		-892		-811
Income from continuing operations including noncontrolling interests									1,326		1,812		1,454
Other income									250		265		223
Impairment									13		8		14
Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations including noncontrolling interests before income taxes									152		130
Income tax expense									-59		-53
Income from continuing operations including noncontrolling interests									93		77
Unrealized gains and losses on investment securities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations including noncontrolling interests before income taxes									-87		-90
Income tax expense									33		35
Income from continuing operations including noncontrolling interests									-54		-55
Other income									-100		-98
Impairment									13		8
Unrecognized pension and other postretirement benefit costs | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations including noncontrolling interests before income taxes									57		94
Income tax expense									-24		-39
Income from continuing operations including noncontrolling interests									33		55
Prior-service costs (credits)									-12		-8
Actuarial losses									69		102
Commodity | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operating Revenue									130		58
Purchased gas									13		47
Electric fuel and other energy-related purchases									-7		10
Interest rate | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest and related charges									16		15
Dominion Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operating Revenue	510	391	428	569	533	388	430	586	1,898	[1]	1,937	[1]	1,677	[1]
Purchased gas									315	[1]	323	[1]	235	[1]
Interest and related charges									27	[1]	28	[1]	40	[1]
Income from continuing operations including noncontrolling interests before income taxes									846		762		747
Income tax expense									-334		-301		-288
Other income									22		28		37
Dominion Gas Holdings, LLC | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations including noncontrolling interests before income taxes									13		16
Income tax expense									-5		-5
Income from continuing operations including noncontrolling interests									8		11
Dominion Gas Holdings, LLC | Unrecognized pension and other postretirement benefit costs | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations including noncontrolling interests before income taxes									8		10
Income tax expense									-3		-4
Income from continuing operations including noncontrolling interests									5		6
Prior-service costs (credits)									1		1
Actuarial losses									7		9
Dominion Gas Holdings, LLC | Commodity | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operating Revenue									-2		2
Purchased gas									14		14
Dominion Gas Holdings, LLC | Interest rate | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest and related charges									1
Virginia Electric and Power Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operating Revenue	1,814	2,053	1,729	1,983	1,745	2,059	1,710	1,781	7,579	[2]	7,295	[2]	7,226	[2]
Electric fuel and other energy-related purchases									2,406	[2]	2,304	[2]	2,368	[2]
Interest and related charges									411		369		385
Income from continuing operations including noncontrolling interests before income taxes									1,406		1,797		1,703
Income tax expense									-548		-659		-653
Other income									93		86		96
Impairment									2		1		1
Virginia Electric and Power Company | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations including noncontrolling interests before income taxes									-5
Income tax expense									2
Income from continuing operations including noncontrolling interests									-3
Virginia Electric and Power Company | Unrealized gains and losses on investment securities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations including noncontrolling interests before income taxes									-10		-5
Income tax expense									4		2
Income from continuing operations including noncontrolling interests									-6		-3
Other income									-10		-6
Impairment											1
Virginia Electric and Power Company | Commodity | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Electric fuel and other energy-related purchases									-5
Virginia Electric and Power Company | Interest rate | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest and related charges									$0
[1]	See Note 24 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to affiliates.

Equity_Summary_of_Restricted_S

Equity (Summary of Restricted Stock and Goal-Based Stock Activity) (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested beginning, Shares	1,007	1,085	1,301
Granted, Shares	354	312	390
Vested, Shares	-278	-356	-596
Cancelled and forfeited, Shares	-18	-34	-10
Nonvested ending, Shares	1,065	1,007	1,085
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Nonvested beginning, Weighted Average Grant Date Fair Value	$49.35	$44.46	$37.37
Granted, Weighted Average Grant Date Fair Value	$67.98	$54.70	$51.14
Vested, Weighted Average Grant Date Fair Value	$44.50	$39	$33.31
Cancelled and forfeited, Weighted Average Grant Date Fair Value	$53.61	$51.11	$42.99
Nonvested ending, Weighted Average Grant Date Fair Value	$56.74	$49.35	$44.46
Goal-Based Stock
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested beginning, Shares	5	4	12
Granted, Shares	13	4	1
Vested, Shares	-1	-2	-9
Cancelled and forfeited, Shares		-1
Nonvested ending, Shares	17	5	4
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Nonvested beginning, Weighted Average Grant Date Fair Value	$53.85	$45.60	$39.19
Granted, Weighted Average Grant Date Fair Value	$68.83	$54.17	$52.48
Vested, Weighted Average Grant Date Fair Value	$52.48	$43.54	$37.46
Cancelled and forfeited, Weighted Average Grant Date Fair Value		$43.54
Nonvested ending, Weighted Average Grant Date Fair Value	$65.15	$53.85	$45.60

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)	3 Months Ended			12 Months Ended						3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Jun. 30, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Sep. 30, 2014
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return on plan assets				$706		$959
Expected return on pension and other postretirement plan assets				610		554
Federal subsidy received				4		5
Decrease in other postretirement benefit obligations due to federal subsidy				20
Net actuarial loss				25
Reduction in net periodic benefit cost for next year	8		36
Reduction in accumulated postretirement benefit obligation	220					220
Period for reduction in net periodic benefit cost						5 years
Accumulated benefit obligation	5,100			6,000		5,100
Estimated reduction in net cumulative required contributions				200
Cumulative required contribution period (years)				10 years
Expected contribution to voluntary employees beneficiary association				12
Percentage coverage of US stock market				7.00%
Employer contributions				41		40		40
U.S. equity:
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined benefit plan, actual plan asset allocations				28.00%
Non-U.S. equity:
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined benefit plan, actual plan asset allocations				18.00%
Fixed Income
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined benefit plan, actual plan asset allocations				33.00%
Real estate:
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined benefit plan, actual plan asset allocations				3.00%
Other alternative investments
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined benefit plan, actual plan asset allocations				18.00%
Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Expected reduction in net periodic benefit cost						40
Investment grade bonds average weighted maturity period				4 years
Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Expected reduction in net periodic benefit cost						60
Investment grade bonds average weighted maturity period				12 years
Virginia Electric and Power Company
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Employer contributions				17		16		15
Virginia Electric and Power Company | Other operations and maintenance expense
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Net periodic benefit cost				75		96		72
Virginia Electric and Power Company | Dominion Retiree Health And Welfare Plan | Other operations and maintenance expense
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Net periodic benefit cost				-18		5		13
Dominion Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return on plan assets				157		214
Expected return on pension and other postretirement plan assets				138		125
Federal subsidy received						1
Net actuarial loss				3
Reduction in net periodic benefit cost for next year			2
Accumulated benefit obligation	534			604		534
Employer contributions				7		7		6
Dominion Gas Holdings, LLC | Dominion Retiree Health And Welfare Plan | Multiemployer Plans, Postretirement Benefit
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Amount of contributions to VEBAs				1		2
Dominion Gas Holdings, LLC | Dominion Retiree Health And Welfare Plan | Multiemployer Plans, Postretirement Benefit | Other operations and maintenance expense
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Net periodic benefit cost				-5		1		3
Pension Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return on plan assets				601		781
Expected return on pension and other postretirement plan assets				499		462		430
Actuarial (gains) losses during the year				131
Net actuarial loss				160
Medicare Part D reimbursement			354
Discount rate			4.80%	5.30%
Reduction in accumulated postretirement benefit obligation	-22	[1]		-1	[1]	-22	[1]	0	[1]
Discount rate								5.50%
Expected long-term rate of return on plan assets				8.75%		8.50%		8.50%
Net periodic benefit cost				20		106		89
Employer contributions				15		8
Pension Benefits | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate	5.20%	[2]		4.40%	[2]	5.20%	[2]
Discount rate				5.20%		4.40%
Pension Benefits | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate	5.30%	[2]				5.30%	[2]
Discount rate				5.30%		4.80%
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return on plan assets				136		176
Expected return on pension and other postretirement plan assets				115		106		96
Actuarial (gains) losses during the year				10
Net actuarial loss				20
Medicare Part D reimbursement			28
Discount rate	5.20%			4.40%		5.20%
Discount rate				5.20%				5.50%
Expected long-term rate of return on plan assets				8.75%		8.50%		8.50%
Net periodic benefit cost				-55		-39		-30
Employer contributions				0		0
Pension Benefits | Dominion Gas Holdings, LLC | Other operations and maintenance expense
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Net periodic benefit cost				-37		-27		-25
Pension Benefits | Dominion Gas Holdings, LLC | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate						4.40%
Pension Benefits | Dominion Gas Holdings, LLC | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate						4.80%
Other Postretirement Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return on plan assets				105		178
Expected return on pension and other postretirement plan assets				111		92		79
Actuarial (gains) losses during the year				32
Net actuarial loss				6
Medicare Part D reimbursement			78
Discount rate	4.80%		4.70%	5.10%		4.80%
Reduction in accumulated postretirement benefit obligation	-7	[1]		0	[1]	-7	[1]	-2	[1]
Discount rate								5.50%
Expected long-term rate of return on plan assets				8.50%		7.75%		7.75%
Net periodic benefit cost				-38		2		33
Employer contributions				12		12
Other Postretirement Benefits | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate	5.00%	[2]		4.40%	[2]	5.00%	[2]
Discount rate				4.20%		4.40%
Expected long-term rate of return on plan assets				7.75%
Other Postretirement Benefits | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate	5.10%	[2]				5.10%	[2]
Discount rate				5.10%		4.80%
Expected long-term rate of return on plan assets				8.50%
Other Postretirement Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return on plan assets				21		38
Expected return on pension and other postretirement plan assets				23		19		16
Actuarial (gains) losses during the year				7
Net actuarial loss				2
Medicare Part D reimbursement			9
Discount rate	5.00%			4.40%		5.00%
Discount rate								5.50%
Expected long-term rate of return on plan assets				8.50%		7.75%		7.75%
Net periodic benefit cost				-5		-1		2
Employer contributions				10		10
Other Postretirement Benefits | Dominion Gas Holdings, LLC | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate				4.20%		4.40%
Other Postretirement Benefits | Dominion Gas Holdings, LLC | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate				5.00%		4.70%
Other Postretirement Benefits | East Ohio
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Retirement age										65 years
Increase in accumulated postretirement benefit obligation due to amendment										22
Reduction in net periodic benefit credit due to amendment										$1
Discount rate										4.20%
Expected long-term rate of return on plan assets										8.50%
[1]	2013 amounts relate primarily to the decommissioning of Kewaunee.
[2]	2013 pension and other postretirement benefits discount rates: 5.20% and 5.00% for the gas union plans and 5.30% and 5.10% for the nonunion and other union plans, respectively.

Employee_Benefit_Plans_Pension

Employee Benefit Plans (Pension Plan and Other Postretirement Benefit Plan Obligations and Plan Assets and Includes a Statement of the Plans Funded Status) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012	Jun. 30, 2013
Changes in fair value of plan assets:
Actual return on plan assets	$706		$959
Employer contributions	41		40		40
Dominion Gas Holdings, LLC
Changes in fair value of plan assets:
Actual return on plan assets	157		214
Employer contributions	7		7		6
Pension Benefits
Changes in benefit obligation:
Benefit obligation at beginning of year	5,625		6,125
Service cost	114		131		116
Interest cost	290		271		268
Benefits paid	-236		-229
Actuarial (gains) losses during the year	887		-650
Plan amendments	0	[1]	1	[1]
Settlements and curtailments	-13	[2]	-24	[2]
Special termination benefits	0		0		0
Medicare Part D reimbursement	0		0
Benefit obligation at end of year	6,667		5,625		6,125
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	6,113		5,553
Actual return on plan assets	601		781
Employer contributions	15		8
Benefits paid	-236		-229
Settlements	-13	[2]	0	[2]
Fair value of plan assets at end of year	6,480		6,113		5,553
Funded status at end of year	-187		488
Noncurrent pension and other postretirement benefit assets	946		913
Other current liabilities	-13		-15
Noncurrent pension and other postretirement benefit liabilities	-1,120		-410
Net amount recognized	-187		488
Discount rate	5.30%					4.80%
Weighted average rate of increase for compensation	4.22%		4.21%
Expected long-term rate of return on plan assets	8.75%		8.50%		8.50%
Pension Benefits | Gas Union Plans
Changes in fair value of plan assets:
Discount rate	5.20%
Pension Benefits | Minimum
Changes in fair value of plan assets:
Discount rate	4.40%	[3]	5.20%	[3]
Pension Benefits | Maximum
Changes in fair value of plan assets:
Discount rate			5.30%	[3]
Pension Benefits | Dominion Gas Holdings, LLC
Changes in benefit obligation:
Benefit obligation at beginning of year	563		607
Service cost	12		13		11
Interest cost	28		27		28
Benefits paid	-29		-27
Actuarial (gains) losses during the year	64		-57
Plan amendments	0		0
Medicare Part D reimbursement	0		0
Benefit obligation at end of year	638		563		607
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	1,403		1,254
Actual return on plan assets	136		176
Employer contributions	0		0
Benefits paid	-29		-27
Fair value of plan assets at end of year	1,510		1,403		1,254
Funded status at end of year	872		840
Noncurrent pension and other postretirement benefit assets	872		840
Noncurrent pension and other postretirement benefit liabilities	0	[4]	0	[4]
Net amount recognized	872		840
Discount rate	4.40%		5.20%
Weighted average rate of increase for compensation	3.93%		3.93%
Expected long-term rate of return on plan assets	8.75%		8.50%		8.50%
Other Postretirement Benefits
Changes in benefit obligation:
Benefit obligation at beginning of year	1,360		1,719
Service cost	32		43		44
Interest cost	67		73		79
Benefits paid	-78		-75
Actuarial (gains) losses during the year	177		-170
Plan amendments	9	[1]	-220	[1]
Settlements and curtailments	0	[2]	-16	[2]
Special termination benefits	0		1		0
Medicare Part D reimbursement	4		5
Benefit obligation at end of year	1,571		1,360		1,719
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	1,315		1,156
Actual return on plan assets	105		178
Employer contributions	12		12
Benefits paid	-30		-31
Settlements	0	[2]	0	[2]
Fair value of plan assets at end of year	1,402		1,315		1,156
Funded status at end of year	-169		-45
Noncurrent pension and other postretirement benefit assets	10		29
Other current liabilities	-3		-3
Noncurrent pension and other postretirement benefit liabilities	-176		-71
Net amount recognized	-169		-45
Discount rate	5.10%		4.80%			4.70%
Weighted average rate of increase for compensation	4.22%		4.22%
Expected long-term rate of return on plan assets	8.50%		7.75%		7.75%
Other Postretirement Benefits | Gas Union Plans
Changes in fair value of plan assets:
Discount rate	5.00%
Other Postretirement Benefits | Minimum
Changes in fair value of plan assets:
Discount rate	4.40%	[3]	5.00%	[3]
Expected long-term rate of return on plan assets	7.75%
Other Postretirement Benefits | Maximum
Changes in fair value of plan assets:
Discount rate			5.10%	[3]
Expected long-term rate of return on plan assets	8.50%
Other Postretirement Benefits | Dominion Gas Holdings, LLC
Changes in benefit obligation:
Benefit obligation at beginning of year	269		287
Service cost	6		7		7
Interest cost	13		12		14
Benefits paid	-16		-17
Actuarial (gains) losses during the year	38		-21
Plan amendments	9		0
Medicare Part D reimbursement	1		1
Benefit obligation at end of year	320		269		287
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	273		242
Actual return on plan assets	21		38
Employer contributions	10		10
Benefits paid	-16		-17
Fair value of plan assets at end of year	288		273		242
Funded status at end of year	-32		4
Noncurrent pension and other postretirement benefit assets	0		19
Noncurrent pension and other postretirement benefit liabilities	-32	[4]	-15	[4]
Net amount recognized	($32)		$4
Discount rate	4.40%		5.00%
Weighted average rate of increase for compensation	3.93%		3.93%
Expected long-term rate of return on plan assets	8.50%		7.75%		7.75%
[1]	2013 other postretirement benefits amount relates to a plan amendment that changed medical coverage for certain Medicare-eligible retirees.
[2]	2014 amounts relate primarily to a settlement charge for certain executives. 2013 amounts relate primarily to the decommissioning of Kewaunee.
[3]	2013 pension and other postretirement benefits discount rates: 5.20% and 5.00% for the gas union plans and 5.30% and 5.10% for the nonunion and other union plans, respectively.
[4]	Reflected in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.

Employee_Benefit_Plans_Benefit

Employee Benefit Plans (Benefit Obligation in Excess of Plan Assets) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	$5,970	$4,978
Fair value of plan assets	4,838	4,553
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	0	0
Fair value of plan assets	0	0
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	1,564	1,233
Fair value of plan assets	1,385	1,158
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	320	147
Fair value of plan assets	$288	$132

Employee_Benefit_Plans_Accumul

Employee Benefit Plans (Accumulated Benefit Obligation in Excess of Plan Assets) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Accumulated benefit obligation	$5,370	$114
Fair value of plan assets	$4,838	$0

Employee_Benefit_Plans_Benefit1

Employee Benefit Plans (Benefit Payments Expected Future Service) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
2015	$272
2016	284
2017	300
2018	320
2019	333
2020-2024	1,925
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
2015	34
2016	35
2017	37
2018	38
2019	39
2020-2024	204
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
2015	91
2016	94
2017	98
2018	101
2019	102
2020-2024	523
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
2015	18
2016	19
2017	20
2018	21
2019	22
2020-2024	$111

Employee_Benefit_Plans_Fair_va

Employee Benefit Plans (Fair values of pension and post retirement plan assets by asset category) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	$6,469	[1]	$6,113	[1]
Pending sales of securities	31
Net accrued income	18
Pending purchases of securities	38
Pension Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	38		179
Pension Benefits | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1,313		1,220
Pension Benefits | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	530		514
Pension Benefits | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	234		308
Pension Benefits | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	403		391
Pension Benefits | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1,595	[2]	1,387	[2]
Pension Benefits | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	711		494
Pension Benefits | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	416		231
Pension Benefits | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	70		176
Pension Benefits | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	86		57
Pension Benefits | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	40		32
Pension Benefits | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	209		227
Pension Benefits | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	518		530
Pension Benefits | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	144		180
Pension Benefits | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	162		187
Pension Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2,668	[1]	2,639	[1]
Pension Benefits | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	13		53
Pension Benefits | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1,313		1,220
Pension Benefits | Level 1 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	530		514
Pension Benefits | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	234		308
Pension Benefits | Level 1 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	403		391
Pension Benefits | Level 1 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[2]	0	[2]
John Hancock insurance contracts held	360		560
Pension Benefits | Level 1 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	45		43
Pension Benefits | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	74		2
Pension Benefits | Level 1 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	10		69
Pension Benefits | Level 1 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	6		7
Pension Benefits | Level 1 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	40		32
Pension Benefits | Level 1 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 1 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 1 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 1 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2,768	[1]	2,350	[1]
Pension Benefits | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	25		126
Pension Benefits | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1,595	[2]	1,387	[2]
Pension Benefits | Level 2 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	666		451
Pension Benefits | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	342		229
Pension Benefits | Level 2 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	60		107
Pension Benefits | Level 2 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	80		50
Pension Benefits | Level 2 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 2 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1,033	[1]	1,124	[1]
Pension Benefits | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[2]	0	[2]
Pension Benefits | Level 3 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Level 3 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	209		227
Pension Benefits | Level 3 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	518		530
Pension Benefits | Level 3 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	144		180
Pension Benefits | Level 3 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	162		187
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1,508	[3]	1,403	[3]
Pending sales of securities	7
Net accrued income	4
Pending purchases of securities	9
Pension Benefits | Dominion Gas Holdings, LLC | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	9		41
Pension Benefits | Dominion Gas Holdings, LLC | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	306		280
Pension Benefits | Dominion Gas Holdings, LLC | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	124		118
Pension Benefits | Dominion Gas Holdings, LLC | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	54		72
Pension Benefits | Dominion Gas Holdings, LLC | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	94		90
Pension Benefits | Dominion Gas Holdings, LLC | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	372	[4]	318	[4]
Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	166		113
Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	97		53
Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	16		40
Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	20		13
Pension Benefits | Dominion Gas Holdings, LLC | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	9		7
Pension Benefits | Dominion Gas Holdings, LLC | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	48		52
Pension Benefits | Dominion Gas Holdings, LLC | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	121		122
Pension Benefits | Dominion Gas Holdings, LLC | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	34		41
Pension Benefits | Dominion Gas Holdings, LLC | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	38		43
Pension Benefits | Dominion Gas Holdings, LLC | Level 1
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	621	[3]	608	[3]
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	3		12
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	306		280
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	124		118
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	54		72
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	94		90
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[4]	0	[4]
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	11		10
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	17		1
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2		16
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1		2
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	9		7
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	646	[3]	537	[3]
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	6		29
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	372	[4]	318	[4]
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	155		103
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	80		52
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	14		24
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	19		11
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	241	[3]	258	[3]
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[4]	0	[4]
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	48		52
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	121		122
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	34		41
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	38		43
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1,402		1,315
Other Postretirement Plans | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	8		17
Other Postretirement Plans | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	514		472
Other Postretirement Plans | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	28		26
Other Postretirement Plans | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	102		111
Other Postretirement Plans | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	21		20
Other Postretirement Plans | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	555	[5]	502	[5]
Other Postretirement Plans | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	38		25
Other Postretirement Plans | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	22		12
Other Postretirement Plans | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	4		9
Other Postretirement Plans | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	4		3
Other Postretirement Plans | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2		2
Other Postretirement Plans | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	19		19
Other Postretirement Plans | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	58		60
Other Postretirement Plans | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	18		27
Other Postretirement Plans | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	9		10
Other Postretirement Plans | Level 1
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	676		640
Other Postretirement Plans | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1		3
Other Postretirement Plans | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	514		472
Other Postretirement Plans | Level 1 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	28		26
Other Postretirement Plans | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	102		111
Other Postretirement Plans | Level 1 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	21		20
Other Postretirement Plans | Level 1 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[5]	0	[5]
John Hancock insurance contracts held	19		29
Other Postretirement Plans | Level 1 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	3		2
Other Postretirement Plans | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	4		0
Other Postretirement Plans | Level 1 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	1		4
Other Postretirement Plans | Level 1 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 1 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2		2
Other Postretirement Plans | Level 1 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 1 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 1 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 1 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	622		559
Other Postretirement Plans | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	7		14
Other Postretirement Plans | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	555	[5]	502	[5]
Other Postretirement Plans | Level 2 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	35		23
Other Postretirement Plans | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	18		12
Other Postretirement Plans | Level 2 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	3		5
Other Postretirement Plans | Level 2 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	4		3
Other Postretirement Plans | Level 2 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 2 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	104		116
Other Postretirement Plans | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[5]	0	[5]
Other Postretirement Plans | Level 3 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Real estate: | REITs
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Level 3 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	19		19
Other Postretirement Plans | Level 3 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	58		60
Other Postretirement Plans | Level 3 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	18		27
Other Postretirement Plans | Level 3 | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	9		10
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	288		273
Other Postretirement Plans | Dominion Gas Holdings, LLC | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2		3
Other Postretirement Plans | Dominion Gas Holdings, LLC | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	113		104
Other Postretirement Plans | Dominion Gas Holdings, LLC | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	26		26
Other Postretirement Plans | Dominion Gas Holdings, LLC | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	129	[4]	119	[4]
Other Postretirement Plans | Dominion Gas Holdings, LLC | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2		2
Other Postretirement Plans | Dominion Gas Holdings, LLC | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	12		12
Other Postretirement Plans | Dominion Gas Holdings, LLC | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	4		7
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	139		130
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	113		104
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	26		26
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[4]	0	[4]
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	131		122
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2		3
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	129	[4]	119	[4]
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	18		21
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0		0
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	0	[4]	0	[4]
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Real estate: | Partnerships
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	2		2
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	12		12
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Pension plan assets by asset category	$4		$7
[1]	Includes net assets related to pending sales of securities of $31 million, net accrued income of $18 million, and excludes net assets related to pending purchases of securities of $38 million at December 31, 2014.
[2]	Common/Collective Trust Funds include $360 million and $560 million of John Hancock insurance contracts held at December 31, 2014 and 2013, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
[3]	Includes net assets related to pending sales of securities of $7 million, net accrued income of $4 million, and excludes net assets related to pending purchases of securities of $9 million at December 31, 2014.
[4]	See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
[5]	Common/Collective Trust Funds include $19 million and $29 million of John Hancock insurance contracts held at December 31, 2014 and 2013, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.

Employee_Benefit_Plans_Pension1

Employee Benefit Plans (Pension plan and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Pension Benefits
Actual return on plan assets:
Fair value of plan assets at end of year	$6,480	$6,113	$5,553
Pension Benefits | Level 3
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	1,124	1,190	1,285
Actual return on plan assets:
Relating to assets still held at the reporting date	126	166	105
Relating to assets sold during the period	-115	-122	-62
Purchases	145	153	129
Sales	-247	-263	-267
Fair value of plan assets at end of year	1,033	1,124	1,190
Pension Benefits | Level 3 | Real estate:
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	227	321	304
Actual return on plan assets:
Relating to assets still held at the reporting date	40	15	21
Relating to assets sold during the period	-18	-36	-8
Purchases	0	6	35
Sales	-40	-79	-31
Fair value of plan assets at end of year	209	227	321
Pension Benefits | Level 3 | Private equity
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	530	456	448
Actual return on plan assets:
Relating to assets still held at the reporting date	70	98	46
Relating to assets sold during the period	-67	-48	-41
Purchases	135	115	79
Sales	-150	-91	-76
Fair value of plan assets at end of year	518	530	456
Pension Benefits | Level 3 | Debt
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	180	192	243
Actual return on plan assets:
Relating to assets still held at the reporting date	12	32	17
Relating to assets sold during the period	-26	-34	-11
Purchases	10	32	15
Sales	-32	-42	-72
Fair value of plan assets at end of year	144	180	192
Pension Benefits | Level 3 | Hedge funds
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	187	221	290
Actual return on plan assets:
Relating to assets still held at the reporting date	4	21	21
Relating to assets sold during the period	-4	-4	-2
Purchases	0	0	0
Sales	-25	-51	-88
Fair value of plan assets at end of year	162	187	221
Pension Benefits | Dominion Gas Holdings, LLC
Actual return on plan assets:
Fair value of plan assets at end of year	1,510	1,403	1,254
Pension Benefits | Dominion Gas Holdings, LLC | Level 3
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	258	268	285
Actual return on plan assets:
Relating to assets still held at the reporting date	31	40	26
Relating to assets sold during the period	-26	-26	-13
Purchases	32	33	27
Sales	-54	-57	-57
Fair value of plan assets at end of year	241	258	268
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Real estate:
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	52	72	68
Actual return on plan assets:
Relating to assets still held at the reporting date	9	4	6
Relating to assets sold during the period	-4	-8	-2
Purchases	0	1	7
Sales	-9	-17	-7
Fair value of plan assets at end of year	48	52	72
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Private equity
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	122	103	99
Actual return on plan assets:
Relating to assets still held at the reporting date	17	24	12
Relating to assets sold during the period	-15	-10	-9
Purchases	30	25	17
Sales	-33	-20	-16
Fair value of plan assets at end of year	121	122	103
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Debt
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	41	43	54
Actual return on plan assets:
Relating to assets still held at the reporting date	4	7	4
Relating to assets sold during the period	-6	-7	-2
Purchases	2	7	3
Sales	-7	-9	-16
Fair value of plan assets at end of year	34	41	43
Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Hedge funds
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	43	50	64
Actual return on plan assets:
Relating to assets still held at the reporting date	1	5	4
Relating to assets sold during the period	-1	-1	0
Purchases	0	0	0
Sales	-5	-11	-18
Fair value of plan assets at end of year	38	43	50
Other Postretirement Plans
Actual return on plan assets:
Fair value of plan assets at end of year	1,402	1,315	1,156
Other Postretirement Plans | Level 3
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	116	124	137
Actual return on plan assets:
Relating to assets still held at the reporting date	13	8	9
Relating to assets sold during the period	-11	5	-1
Purchases	14	10	9
Sales	-28	-31	-30
Fair value of plan assets at end of year	104	116	124
Other Postretirement Plans | Level 3 | Real estate:
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	19	24	24
Actual return on plan assets:
Relating to assets still held at the reporting date	4	-2	1
Relating to assets sold during the period	-1	1	0
Purchases	0	1	2
Sales	-3	-5	-3
Fair value of plan assets at end of year	19	19	24
Other Postretirement Plans | Level 3 | Private equity
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	60	58	63
Actual return on plan assets:
Relating to assets still held at the reporting date	7	6	3
Relating to assets sold during the period	-7	3	-1
Purchases	13	7	6
Sales	-15	-14	-13
Fair value of plan assets at end of year	58	60	58
Other Postretirement Plans | Level 3 | Debt
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	27	31	36
Actual return on plan assets:
Relating to assets still held at the reporting date	2	3	4
Relating to assets sold during the period	-3	0	0
Purchases	1	2	1
Sales	-9	-9	-10
Fair value of plan assets at end of year	18	27	31
Other Postretirement Plans | Level 3 | Hedge funds
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	10	11	14
Actual return on plan assets:
Relating to assets still held at the reporting date	0	1	1
Relating to assets sold during the period	0	1	0
Purchases	0	0	0
Sales	-1	-3	-4
Fair value of plan assets at end of year	9	10	11
Other Postretirement Plans | Dominion Gas Holdings, LLC
Actual return on plan assets:
Fair value of plan assets at end of year	288	273	242
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	21	24	28
Actual return on plan assets:
Relating to assets still held at the reporting date	3	2	-2
Relating to assets sold during the period	-2	0	3
Purchases	2	1	1
Sales	-6	-6	-6
Fair value of plan assets at end of year	18	21	24
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Real estate:
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	2	3	3
Actual return on plan assets:
Relating to assets still held at the reporting date	0	-1	0
Relating to assets sold during the period	0	0	0
Purchases	0	0	0
Sales	0	0	0
Fair value of plan assets at end of year	2	2	3
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Private equity
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	12	13	15
Actual return on plan assets:
Relating to assets still held at the reporting date	2	2	-1
Relating to assets sold during the period	-1	0	2
Purchases	2	1	1
Sales	-3	-4	-4
Fair value of plan assets at end of year	12	12	13
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Debt
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	7	8	10
Actual return on plan assets:
Relating to assets still held at the reporting date	1	1	-1
Relating to assets sold during the period	-1	0	1
Purchases	0	0	0
Sales	-3	-2	-2
Fair value of plan assets at end of year	4	7	8
Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Hedge funds
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year	0	0	0
Actual return on plan assets:
Relating to assets still held at the reporting date	0	0	0
Relating to assets sold during the period	0	0	0
Purchases	0	0	0
Sales	0	0	0
Fair value of plan assets at end of year	$0	$0	$0

Employee_Benefit_Plans_Net_Per

Employee Benefit Plans (Net Periodic Benefit (Credit) Cost and Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	($610)		($554)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Settlements and curtailments			220
Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	-138		-125
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	114		131		116
Interest cost	290		271		268
Expected return on plan assets	-499		-462		-430
Amortization of prior service (credit) cost	-3		-3		-3
Amortization of net actuarial loss	111		165		132
Settlements and curtailments	1	[1]	-2	[1]	0	[1]
Special termination benefits	0		0		0
Net periodic benefit (credit) cost	20		106		89
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss	784		-968		786
Prior service (credit) cost	0		1		0
Settlements and curtailments	-1	[1]	-22	[1]	0	[1]
Total recognized in other comprehensive income and regulatory assets and liabilities	669		-1,157		651
Significant assumptions used to determine periodic cost:
Discount rate					5.50%
Expected long-term rate of return on plan assets	8.75%		8.50%		8.50%
Weighted average rate of increase for compensation	4.21%		4.21%		4.21%
Pension Benefits | Minimum
Significant assumptions used to determine periodic cost:
Discount rate	5.20%		4.40%
Pension Benefits | Maximum
Significant assumptions used to determine periodic cost:
Discount rate	5.30%		4.80%
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Service cost	12		13		11
Interest cost	28		27		28
Expected return on plan assets	-115		-106		-96
Amortization of prior service (credit) cost	-1		-1		-1
Amortization of net actuarial loss	19		26		26
Net periodic benefit (credit) cost	-55		-39		-30
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss	43		-127		35
Prior service (credit) cost	0		0		0
Total recognized in other comprehensive income and regulatory assets and liabilities	23		-154		8
Significant assumptions used to determine periodic cost:
Discount rate	5.20%				5.50%
Expected long-term rate of return on plan assets	8.75%		8.50%		8.50%
Weighted average rate of increase for compensation	3.93%		3.93%		3.93%
Pension Benefits | Dominion Gas Holdings, LLC | Minimum
Significant assumptions used to determine periodic cost:
Discount rate			4.40%
Pension Benefits | Dominion Gas Holdings, LLC | Maximum
Significant assumptions used to determine periodic cost:
Discount rate			4.80%
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost	32		43		44
Interest cost	67		73		79
Expected return on plan assets	-111		-92		-79
Amortization of prior service (credit) cost	28		15		13
Amortization of net actuarial loss	2		7		6
Settlements and curtailments	0	[1]	-15	[1]	-4	[1]
Special termination benefits	0		1		0
Net periodic benefit (credit) cost	-38		2		33
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss	183		-255		139
Prior service (credit) cost	9		-215		1
Settlements and curtailments	0	[1]	-7	[1]	-2	[1]
Total recognized in other comprehensive income and regulatory assets and liabilities	218		-469		145
Significant assumptions used to determine periodic cost:
Discount rate					5.50%
Expected long-term rate of return on plan assets	8.50%		7.75%		7.75%
Weighted average rate of increase for compensation	4.22%		4.22%		4.22%
Healthcare cost trend rate	7.00%	[2]	7.00%	[2]	7.00%	[2]
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.00%	[2]	4.60%	[2]	4.60%	[2]
Year that the rate reaches the ultimate trend rate	2018	[2],[3]	2062	[2],[3]	2061	[2],[3]
Other Postretirement Plans | Minimum
Significant assumptions used to determine periodic cost:
Discount rate	4.20%		4.40%
Expected long-term rate of return on plan assets	7.75%
Other Postretirement Plans | Maximum
Significant assumptions used to determine periodic cost:
Discount rate	5.10%		4.80%
Expected long-term rate of return on plan assets	8.50%
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Service cost	6		7		7
Interest cost	13		12		14
Expected return on plan assets	-23		-19		-16
Amortization of prior service (credit) cost	1		3		4
Amortization of net actuarial loss	0		2		1
Net periodic benefit (credit) cost	-5		-1		2
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss	40		-40		12
Prior service (credit) cost	10		0		0
Total recognized in other comprehensive income and regulatory assets and liabilities	$51		($39)		$15
Significant assumptions used to determine periodic cost:
Discount rate					5.50%
Expected long-term rate of return on plan assets	8.50%		7.75%		7.75%
Weighted average rate of increase for compensation	3.93%		3.93%		3.93%
Healthcare cost trend rate	7.00%	[2]	7.00%	[2]	7.00%	[2]
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.00%	[2]	4.60%	[2]	4.60%	[2]
Year that the rate reaches the ultimate trend rate	2018	[2],[3]	2062	[2],[3]	2061	[2],[3]
Other Postretirement Plans | Dominion Gas Holdings, LLC | Minimum
Significant assumptions used to determine periodic cost:
Discount rate	4.20%		4.40%
Other Postretirement Plans | Dominion Gas Holdings, LLC | Maximum
Significant assumptions used to determine periodic cost:
Discount rate	5.00%		4.70%
[1]	2013 amounts relate primarily to the decommissioning of Kewaunee.
[2]	Assumptions used to determine net periodic cost for the following year.
[3]	The Society of Actuaries model used to determine healthcare cost trend rates was updated in 2014. The new model converges to the ultimate trend rate much more quickly than previous models.

Employee_Benefit_Plans_AOCI_an

Employee Benefit Plans (AOCI and regulatory assets and liabilities that have not been recognized as components of periodic benefit (credit) cost) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss	($416)		($324)		($877)
Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss	-86		-58		-140
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss	2,382		1,709
Prior service (credit) cost	7		10
Total	2,389	[1]	1,719	[1]
Related expenses	2,400		1,700
Amount included in AOCI	1,400		1,000
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss	303		279
Prior service (credit) cost	1		2
Total	304	[1]	281	[1]
Related expenses	304		281
Amount included in AOCI	112		104
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss	139		-40
Prior service (credit) cost	-233		-271
Total	-94	[1]	-311	[1]
Related expenses	-94		-311
Amount included in AOCI	-81		-156
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss	43		3
Prior service (credit) cost	7		-4
Total	50	[1]	-1	[1]
Amount included in AOCI	$50		($1)
[1]	As of December 31, 2014, of the $2.4 billion and $(94) million related to pension benefits and other postretirement benefits, $1.4 billion and $(81) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2013, of the $1.7 billion and $(311) million related to pension benefits and other postretirement benefits, $1.0 billion and $(156) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.

Employee_Benefit_Plans_Compone

Employee Benefit Plans (Components of AOCI and Regulatory Assets and Liabilities) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	$25
Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	3
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	160
Prior service (credit) cost	2
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	20
Prior service (credit) cost	1
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	6
Prior service (credit) cost	-27
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	2
Prior service (credit) cost	$0

Employee_Benefit_Plans_Effect_

Employee Benefit Plans (Effect of One Percentage Point Change on Benefit Plans) (Details) (Other Postretirement Plans, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Effect of one percentage point increase on total of service and interest cost components	$26
Effect of one percentage point increase on other postretirement benefit obligation	186
Effect of one percentage point decrease on total of service and interest cost components	-16
Effect of one percentage point decrease on other postretirement benefit obligation	-152
Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Effect of one percentage point increase on total of service and interest cost components	5
Effect of one percentage point increase on other postretirement benefit obligation	40
Effect of one percentage point decrease on total of service and interest cost components	-4
Effect of one percentage point decrease on other postretirement benefit obligation	($30)

Commitments_and_Contingencies_1

Commitments and Contingencies (Environmental Matters and Other Legal Matters) (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

1 Months Ended

50 Months Ended

1 Months Ended

3 Months Ended

Jun. 30, 2014

Jul. 31, 2013

Sep. 30, 2011

Jul. 31, 2011

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

31-May-14

Dec. 31, 2014

Sep. 30, 2014

Oct. 31, 2014

Dec. 31, 2013

Unit

Unit

Party

Facility

Facility

Site

Loss Contingencies [Line Items]

Compliance extension period

1 year

Number of coal fired generating units

2

3

Amount spent for emissions controls

$5,345,000,000

$4,065,000,000

$4,145,000,000

Number of parties ordered specific remedial action

22

Maximum civil penalties per day

37,500

Number of former manufactured gas plant sites

17

17

Number of facilities with CCR

8

Period for consideration of CO2 emissions for biomass projects

3 years

Charges associated with proposed settlement for ash pond closure costs

121,000,000

0

0

Required payments

50,000,000

50,000,000

Obligated Payments to Maryland Strategic Energy Investments Fund and Low Income Energy Assistance Programs

Loss Contingencies [Line Items]

Required payments

48,000,000

Obligated Payments to Maryland Strategic Energy Investments Fund

Loss Contingencies [Line Items]

Required payments

40,000,000

Period of required payments

5 years

Low Income Energy Assistance Programs

Loss Contingencies [Line Items]

Required payments

8,000,000

Period of required payments

20 years

Possum Point Power Station

Loss Contingencies [Line Items]

Charges associated with proposed settlement for ash pond closure costs

121,000,000

Clean Air Act

Loss Contingencies [Line Items]

Number of states under EPA Replacement Rule

28

Emissions of fossil fuel fired electric generating units

25

Number of groups of affected states

2

Amount spent for emissions controls

2,000,000

Clean Water Act

Loss Contingencies [Line Items]

Number of facilities

14

Remedial options

Loss Contingencies [Line Items]

Estimates for compliance, minimum

1,000,000

1,000,000

Estimates for compliance, maximum

22,000,000

22,000,000

Breach of Contract Lawsuit | Pending Litigation

Loss Contingencies [Line Items]

Amount of accrued liability

6,000,000

Dominion Gas Holdings, LLC

Loss Contingencies [Line Items]

Amount spent for emissions controls

719,000,000

650,000,000

928,000,000

Number of former manufactured gas plant sites

12

12

Virginia Electric and Power Company

Loss Contingencies [Line Items]

Charge reflecting plant balances that are not expected to be recovered

26,000,000

Charge reflecting plant balances not expected to be recovered, after tax

16,000,000

Amount spent for emissions controls

2,911,000,000

2,394,000,000

2,082,000,000

Number of former manufactured gas plant sites

3

3

Charges associated with proposed settlement for ash pond closure costs

$121,000,000

$0

$0

Virginia Electric and Power Company | Clean Water Act

Loss Contingencies [Line Items]

Number of facilities

11

Commitments_and_Contingencies_2

Commitments and Contingencies (Nuclear Operations) (Narrative) (Details) (USD $)	1 Months Ended	12 Months Ended
	Nov. 30, 2013	Dec. 31, 2014	Dec. 31, 2013
Loss Contingencies [Line Items]
Amount of coverage purchased from commercial insurance pools		$375,000,000
Amount that could be assessed for each licensed reactor		127,000,000
Amount that could be assessed for each licensed reactor per reactor		19,000,000
Coverage that exceeds NRC minimum requirement		1,060,000,000
Maximum assessment for premiums on insurance policy		72,000,000
Maximum assessment for insurance policy		20,000,000
Current fee per kWh for electricity paid by civilian nuclear power generators	1
Waste fee recognized		16,000,000
Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables		69,000,000	79,000,000
Millstone Unit 1
Loss Contingencies [Line Items]
Minimum financial assurance			2,900,000,000
Millstone
Loss Contingencies [Line Items]
Settlement amount		17,000,000
Surry and North Anna
Loss Contingencies [Line Items]
Settlement amount		27,000,000
Kewaunee
Loss Contingencies [Line Items]
Settlement amount		7,000,000	5,000,000
Nuclear Plant
Loss Contingencies [Line Items]
Liability protection under Price-Anderson Act		13,600,000,000
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Maximum assessment for premiums on insurance policy		42,000,000
Maximum assessment for insurance policy		9,000,000
Waste fee recognized		10,000,000
Virginia Electric and Power Company | Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables		41,000,000	50,000,000
Virginia Electric and Power Company | Kewaunee
Loss Contingencies [Line Items]
Minimum financial assurance			$1,800,000,000

Commitments_and_Contingencies_3

Commitments and Contingencies (Nuclear Insurance) (Details) (USD $)	Dec. 31, 2014
Millstone
Guarantor Obligations [Line Items]
Property insurance coverage	$1,700,000
Kewaunee
Guarantor Obligations [Line Items]
Property insurance coverage	1,060,000
Surry | Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Property insurance coverage	1,700,000	[1]
North Anna | Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Property insurance coverage	1,700,000	[1]
Surry and North Anna
Guarantor Obligations [Line Items]
Coverage amount	$200,000,000
[1]	Surry and North Anna share a blanket property limit of $200 million.

Commitment_and_Contingencies_S

Commitment and Contingencies (Schedule of Long Term Purchase Commitments) (Details) (Virginia Electric and Power Company, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Long-term Purchase Commitment [Line Items]
Present value of total commitment for capacity payments	$833
Purchased electric capacity
Long-term Purchase Commitment [Line Items]
2015	313	[1]
2016	250	[1]
2017	158	[1]
2018	104	[1]
2019	65	[1]
Thereafter	99	[1]
Total	989	[1]
Payments	330		345	337
Energy payments
Long-term Purchase Commitment [Line Items]
Payments	$304		$236	$214
[1]	Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities and independent power producers, the last of which ends in 2021. Capacity payments under the contracts are generally based on fixed dollar amounts per month, subject to escalation using broad-based economic indices. At December 31, 2014, the present value of Virginia Power's total commitment for capacity payments is $833 million. Capacity payments totaled $330 million, $345 million, and $337 million, and energy payments totaled $304 million, $236 million, and $214 million for the years ended 2014, 2013 and 2012, respectively.

Commitments_and_Contingencies_4

Commitments and Contingencies (Lease Commitments) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Loss Contingencies [Line Items]
2015	$63
2016	57
2017	49
2018	43
2019	36
Thereafter	79
Total	327
Virginia Electric and Power Company
Loss Contingencies [Line Items]
2015	30
2016	26
2017	21
2018	18
2019	12
Thereafter	26
Total	133
Dominion Gas Holdings, LLC
Loss Contingencies [Line Items]
2015	28
2016	25
2017	23
2018	21
2019	19
Thereafter	25
Total	$141

Commitments_and_Contingencies_5

Commitments and Contingencies (Lease Commitments) (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Loss Contingencies [Line Items]
Rental expense	$92	$101	$112
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Rental expense	43	42	48
Dominion Gas Holdings, LLC
Loss Contingencies [Line Items]
Rental expense	$35	$15	$15

Commitments_and_Contingencies_6

Commitments and Contingencies (Guarantees, Surety Bonds and Letters of Credit) (Narrative) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Guarantor Obligations [Line Items]
Exposure under guarantees	$6,366
Minimum
Guarantor Obligations [Line Items]
Annual future contributions	4
Maximum
Guarantor Obligations [Line Items]
Annual future contributions	19
Third Party and Equity Method Investee
Guarantor Obligations [Line Items]
Estimate of possible loss	74
Exposure under guarantees	49
Third Party and Equity Method Investee | Through 2019
Guarantor Obligations [Line Items]
Exposure under guarantees	$72

Commitments_and_Contingencies_7

Commitments and Contingencies (Subsidiary Guarantees) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
	guarantee
Guarantor Obligations [Line Items]
Stated Limit	$6,366,000,000
Value	1,453,000,000	[1]
Number of DEI subsidiaries	2
Purchased surety bonds	133,000,000
Authorized issuance of standby letters of credit	48,000,000
Debt
Guarantor Obligations [Line Items]
Stated Limit	27,000,000	[2]
Value	27,000,000	[1],[2]
Commodity transactions
Guarantor Obligations [Line Items]
Stated Limit	3,151,000,000	[3]
Value	919,000,000	[1],[3]
Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	215,000,000	[4]
Value	76,000,000	[1],[4]
Solar
Guarantor Obligations [Line Items]
Stated Limit	531,000,000	[5]
Value	396,000,000	[1],[5]
Other
Guarantor Obligations [Line Items]
Stated Limit	532,000,000	[6]
Value	35,000,000	[1],[6]
Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Purchased surety bonds	64,000,000
Virginia Electric and Power Company | Debt
Guarantor Obligations [Line Items]
Stated Limit	14,000,000
Dominion Gas Holdings, LLC
Guarantor Obligations [Line Items]
Purchased surety bonds	30,000,000
Cove Point
Guarantor Obligations [Line Items]
Stated Limit	150,000,000
Number of guarantees with no stated limit	2
Number of guarantees	1
Aggregate limit for guarantees	1,750,000,000
Annual draw limit	175,000,000
Cove Point | Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	1,910,000,000	[7]
Value	0	[1],[7]
Millstone | Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	150,000,000
Kewaunee | Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	$60,000,000
[1]	Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2014 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 commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power, Dominion Gas 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 (in the event of a prolonged outage) and Kewaunee, respectively, 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]	Includes guarantees to facilitate the development of solar projects including guarantees to support the issuance of full notice to proceed under EPC agreements. Includes certain guarantees that do not have stated limits. Also includes guarantees entered into by DEI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects.
[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. As of December 31, 2014, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $72 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million. The value provided includes certain guarantees that do not have stated limits.
[7]	Guarantees related to Cove Point, in support of terminal services, transportation and construction. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million.

Credit_Risk_Narrative_Details

Credit Risk (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Concentration Risk [Line Items]
Gross credit exposure	$228
Gas transportation and storage	1,543	1,535	1,401
Additional collateral to be posted if the credit-related contingent features were triggered	20	146
Collateral already posted	1	76
Fair value of all derivative instruments not fully collateralized	49	169
Investment Grade Counterparties | Investment Grade
Concentration Risk [Line Items]
Concentration of credit risk	86.00%
CounterpartyA
Concentration Risk [Line Items]
Amount of exposure	23
Customer Concentration Risk | DTI | Sales Revenue, Net
Concentration Risk [Line Items]
Concentration of credit risk	94.00%
Number of customers	260
Customer Concentration Risk | East Ohio | Sales Revenue, Net
Concentration Risk [Line Items]
Concentration of credit risk	98.00%
Customer Concentration Risk | Ten Largest Customers | DTI | Sales Revenue, Net
Concentration Risk [Line Items]
Concentration of credit risk	41.00%
Number of customers	10
Customer Concentration Risk | Thirty Largest Customers | DTI | Sales Revenue, Net
Concentration Risk [Line Items]
Concentration of credit risk	74.00%
Number of customers	30
Gas transportation and storage	$718
Customer Concentration Risk | Long Term Capacity Contracts | DTI | Sales Revenue, Net
Concentration Risk [Line Items]
Concentration of credit risk	99.00%
Term of long term contract	3 years
Customer Concentration Risk | Annual Capacity Contracts | DTI | Sales Revenue, Net
Concentration Risk [Line Items]
Concentration of credit risk	1.00%
Customer Concentration Risk | Unsubscribed Firm Transportation Capacity | DTI | Sales Revenue, Net
Concentration Risk [Line Items]
Concentration of credit risk	1.00%

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Commodity purchases from affiliates	$543		$417		$368
Services provided by affiliates	432	[1]	415	[1]	399	[1]
Services provided to affiliates	22		21		19
Virginia Electric and Power Company | Noncurrent Pension and Other Postretirement Benefit Liabilities
Related Party Transaction [Line Items]
Amounts due to affiliate associated with benefit plan	219		144
Virginia Electric and Power Company | Other Deferred Charges and Other Assets
Related Party Transaction [Line Items]
Amounts due from affiliate associated with benefit plan	37		3
Virginia Electric and Power Company | Dominion
Related Party Transaction [Line Items]
Short term demand note borrowings	427		97
Dominion Gas Holdings, LLC
Related Party Transaction [Line Items]
Amounts due to affiliate associated with benefit plan	0	[2]	1	[2]
Amounts due from affiliate associated with benefit plan	3	[3]	6	[3]
Services provided to affiliates	84		109		64
Purchases of natural gas and transportation and storage services from affiliates	34		31		14
Customer receivables from related parties	22	[4]	3	[4]
Affiliated notes receivable	9	[5]	5	[5]
Dominion Gas Holdings, LLC | Revolving Credit Facility | IRCA
Related Party Transaction [Line Items]
Borrowings under IRCA	384		1,300
Interest charges	4		35		61
Dominion Gas Holdings, LLC | Atlantic Coast Pipeline
Related Party Transaction [Line Items]
Customer receivables from related parties	17
Dominion Gas Holdings, LLC | Services provided by affiliates
Related Party Transaction [Line Items]
Purchases of natural gas and transportation and storage services from affiliates	106		116		107
Dominion Gas Holdings, LLC | Services provided by Dominion Gas to affiliates
Related Party Transaction [Line Items]
Services provided by affiliates	17		4		3
Dominion Gas Holdings, LLC | Noncurrent Pension and Other Postretirement Benefit Assets
Related Party Transaction [Line Items]
Amounts due from Dominion	614		577
Dominion Gas Holdings, LLC | Other Deferred Credits and Other Liabilities
Related Party Transaction [Line Items]
Amounts due to affiliate associated with benefit plan	$7		$14
[1]	Includes capitalized expenditures.
[2]	Amounts are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.
[3]	Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.
[4]	Includes $17 million due from Atlantic Coast Pipeline, an affiliated VIE.
[5]	Amounts are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.

Operating_Segments_Narrative_D

Operating Segments (Narrative) (Details) (USD $)	3 Months Ended			12 Months Ended						3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2014
Segment Reporting Information [Line Items]
Total operating expenses				$9,715		$9,804		$9,977
Charge recognized				374		0		0
Charge recognized, net of tax	191	193
Charges associated with proposed settlement for ash pond closure costs				121		0		0
Income (loss) from discontinued operations				0	[1]	92	[1]	1,125	[1]
Impairment charge								1,600
Asset disposition adjustment				42		44
Impairment charge after tax			33
Loss from producer services business after tax			24
Loss from discontinued operations, net of tax				0		92		1,125
Corporate and Other
Segment Reporting Information [Line Items]
Total operating expenses				970		452		1,700
Net expenses attributable to other operating segments				544		184		1,500
Income (loss) from discontinued operations						92		1,125
Asset disposition adjustment				0	[2]	0	[2]
Dominion Generation
Segment Reporting Information [Line Items]
Charges associated with proposed settlement for ash pond closure costs				121
Charge related to settlement offer, net of tax				74
Income (loss) from discontinued operations						0		0
Asset disposition adjustment				32	[3]	19	[3]
Net gain on investments						81
Net gain on investments after tax						49
Dominion Generation | Brayton Point Kincaid And Elwood Power Stations
Segment Reporting Information [Line Items]
Loss before income taxes								1,700
Loss from discontinued operations, net of tax								1,100
Dominion Generation | Legislation enacted
Segment Reporting Information [Line Items]
Charge recognized				374
Charge recognized, net of tax				248
Dominion Energy
Segment Reporting Information [Line Items]
Income (loss) from discontinued operations						0		0
Asset disposition adjustment				10	[4]	25	[4]
Loss from operations						182
Loss from operations after tax						109
Impairment charge						55
Impairment charge after tax						33
Loss from producer services business						127
Loss from producer services business after tax						76
Dominion Energy | Legislation enacted
Segment Reporting Information [Line Items]
Charge recognized				319
Charge recognized, net of tax				193
DVP
Segment Reporting Information [Line Items]
Income (loss) from discontinued operations						0		0
Asset disposition adjustment				0		0
Charge related to Biennial Review Order								87
Restoration costs net of tax								53
Brayton Point and Kincaid
Segment Reporting Information [Line Items]
Loss before income taxes			70
Loss from operations after tax			57
Brayton Point and Kincaid | Dominion Generation
Segment Reporting Information [Line Items]
Loss before income taxes						135
Income (loss) from discontinued operations						92
Amount of debt extinguishment						64
Amount of debt extinguishment after tax						38
Impairment charge						48
Long-lived assets impairment charges, net of tax						28
Loss from discontinued operation						17
Loss on discontinued operation, net of tax						18
Asset disposition adjustment						16
Loss from operations						6
Loss from operations after tax						8
Kewaunee | Dominion Generation
Segment Reporting Information [Line Items]
Loss before income taxes								467
Loss from discontinued operations, net of tax								303
State Line and Salem Harbor | Dominion Generation
Segment Reporting Information [Line Items]
Loss before income taxes								49
Loss from discontinued operations, net of tax								22
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Total operating expenses				5,855		5,215		5,234
Charge recognized				374		0		0
Charge recognized, net of tax	191
Charges associated with proposed settlement for ash pond closure costs				121		0		0
Charge related to settlement offer, net of tax										74
Restoration costs net of tax										28
Virginia Electric and Power Company | Corporate and Other
Segment Reporting Information [Line Items]
Total operating expenses				342		47		51
Virginia Electric and Power Company | Dominion Generation
Segment Reporting Information [Line Items]
Charges associated with proposed settlement for ash pond closure costs				121
Charge related to settlement offer, net of tax				74
Charge related to Biennial Review Order						40
Restoration costs net of tax						28
Virginia Electric and Power Company | Dominion Generation | Legislation enacted
Segment Reporting Information [Line Items]
Charge recognized				374
Charge recognized, net of tax				248
Virginia Electric and Power Company | DVP
Segment Reporting Information [Line Items]
Charge related to Biennial Review Order								87
Restoration costs net of tax								53
Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
Total operating expenses				1,047		1,175		927
Net expenses attributable to other operating segments						41
Asset disposition adjustment				3		7
Impairment charge						55
Impairment charge after tax						33
Severance costs						14
Severance costs net of tax						8
Dominion Gas Holdings, LLC | Corporate and Other
Segment Reporting Information [Line Items]
Net expenses attributable to other operating segments				9		49		10
Asset disposition adjustment				0	[2]	0	[2]
Dominion Gas Holdings, LLC | Dominion Generation
Segment Reporting Information [Line Items]
Asset disposition adjustment				0		0
Dominion Gas Holdings, LLC | Dominion Energy
Segment Reporting Information [Line Items]
Asset disposition adjustment				3	[4]	7	[4]
Dominion Gas Holdings, LLC | DVP
Segment Reporting Information [Line Items]
Asset disposition adjustment				$0		$0
[1]	Includes income tax benefit of $43 million and $692 million in 2013 and 2012, respectively. For 2012, includes impairment charges of $1.6 billion related to Brayton Point and Kincaid. See Note 6 for additional information.
[2]	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.
[3]	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
[4]	Related to assets sold or contributed to an affiliate or Blue Racer.

Operating_Segment_Schedule_of_

Operating Segment (Schedule of Segment Reporting Information, by Segment) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating Revenue	$2,943	$3,050	$2,813	$3,630	$3,185	$3,432	$2,980	$3,523	$12,436		$13,120		$12,835
Total operating revenue									12,436		13,120		12,835
Depreciation, depletion and amortization									1,292		1,208		1,127
Equity in earnings of equity method investees									46		14		25
Interest income									68		54		61
Interest and related charges									1,193		877		816
Income tax expense									452		892		811
Loss from discontinued operations, net of tax									0	[1]	-92	[1]	-1,125	[1]
Net income (loss) attributable to Dominion	243	529	159	379	431	569	202	495	1,310		1,697		302
Investment in equity method affiliates	1,081				916				1,081		916
Capital expenditures									5,551		4,104		4,145
Total assets	54,327				50,096				54,327		50,096
Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue									0		0		0
DVP
Segment Reporting Information [Line Items]
Operating Revenue									1,918		1,825		1,846
Total operating revenue									1,936		1,834		1,855
Depreciation, depletion and amortization									462		427		392
Equity in earnings of equity method investees									0		0		0
Interest income									0		0		1
Interest and related charges									205		175		187
Income tax expense									317		287		278
Loss from discontinued operations, net of tax											0		0
Net income (loss) attributable to Dominion									502		475		439
Investment in equity method affiliates	0				0				0		0
Capital expenditures									1,652		1,361		1,158
Total assets	13,000				11,900				13,000		11,900
DVP | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue									18		9		9
Dominion Generation
Segment Reporting Information [Line Items]
Operating Revenue									7,665		8,445		8,170
Total operating revenue									7,735		8,513		8,274
Depreciation, depletion and amortization									516		518		483
Equity in earnings of equity method investees									-18		-14		3
Interest income									67		66		65
Interest and related charges									240		220		177
Income tax expense									392		483		576
Loss from discontinued operations, net of tax											0		0
Net income (loss) attributable to Dominion									1,101		1,031		1,021
Investment in equity method affiliates	262				280				262		280
Capital expenditures									2,466		1,605		1,615
Total assets	24,200				22,000				24,200		22,000
Dominion Generation | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue									70		68		104
Dominion Energy
Segment Reporting Information [Line Items]
Operating Revenue									1,718		1,783		1,813
Total operating revenue									2,892		2,846		2,743
Depreciation, depletion and amortization									241		228		216
Equity in earnings of equity method investees									54		21		23
Interest income									14		12		30
Interest and related charges									11		26		47
Income tax expense									436		409		352
Loss from discontinued operations, net of tax											0		0
Net income (loss) attributable to Dominion									677		643		551
Investment in equity method affiliates	796				615				796		615
Capital expenditures									1,329		1,043		1,350
Total assets	12,700				12,100				12,700		12,100
Dominion Energy | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue									1,174		1,063		930
Corporate and Other
Segment Reporting Information [Line Items]
Operating Revenue									-12		3		155
Total operating revenue									560		612		763
Depreciation, depletion and amortization									73		35		36
Equity in earnings of equity method investees									10		7		-1
Interest income									20		42		71
Interest and related charges									770		522		511
Income tax expense									-693		-287		-395
Loss from discontinued operations, net of tax											-92		-1,125
Net income (loss) attributable to Dominion									-970		-452		-1,709
Investment in equity method affiliates	23				21				23		21
Capital expenditures									104		95		22
Total assets	8,700				8,500				8,700		8,500
Corporate and Other | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue									572		609		608
Adjustments & Eliminations
Segment Reporting Information [Line Items]
Operating Revenue									1,147		1,064		851
Total operating revenue									-687		-685		-800
Depreciation, depletion and amortization									0		0		0
Equity in earnings of equity method investees									0		0		0
Interest income									-33		-66		-106
Interest and related charges									-33		-66		-106
Income tax expense									0		0		0
Loss from discontinued operations, net of tax											0		0
Net income (loss) attributable to Dominion									0		0		0
Investment in equity method affiliates	0				0				0		0
Capital expenditures									0		0		0
Total assets	-4,300				-4,400				-4,300		-4,400
Adjustments & Eliminations | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue									-1,834		-1,749		-1,651
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating Revenue	1,814	2,053	1,729	1,983	1,745	2,059	1,710	1,781	7,579	[2]	7,295	[2]	7,226	[2]
Total operating revenue									7,579		7,295		7,226
Depreciation, depletion and amortization									915		853		782
Interest income									8		6		8
Interest and related charges									411		369		385
Income tax expense									548		659		653
Net income (loss) attributable to Dominion	151	314	69	324	199	387	265	287	858		1,138		1,050
Capital expenditures									3,107		2,533		2,288
Total assets	29,509				26,961				29,509		26,961
Virginia Electric and Power Company | DVP
Segment Reporting Information [Line Items]
Total operating revenue									1,928		1,826		1,847
Depreciation, depletion and amortization									462		427		392
Interest income									0		0		1
Interest and related charges									205		175		186
Income tax expense									317		286		277
Net income (loss) attributable to Dominion									509		483		448
Capital expenditures									1,651		1,360		1,142
Total assets	13,200				12,000				13,200		12,000
Virginia Electric and Power Company | Dominion Generation
Segment Reporting Information [Line Items]
Total operating revenue									5,651		5,475		5,379
Depreciation, depletion and amortization									416		425		390
Interest income									8		6		7
Interest and related charges									203		192		199
Income tax expense									416		399		403
Net income (loss) attributable to Dominion									691		702		653
Capital expenditures									1,456		1,173		1,146
Total assets	16,400				15,100				16,400		15,100
Virginia Electric and Power Company | Corporate and Other
Segment Reporting Information [Line Items]
Total operating revenue									0		-6		0
Depreciation, depletion and amortization									37		1		0
Interest income									0		0		0
Interest and related charges									3		2		0
Income tax expense									-185		-26		-27
Net income (loss) attributable to Dominion									-342		-47		-51
Capital expenditures									0		0		0
Total assets	0				0				0		0
Virginia Electric and Power Company | Adjustments & Eliminations
Segment Reporting Information [Line Items]
Total operating revenue									0		0		0
Depreciation, depletion and amortization									0		0		0
Interest income									0		0		0
Interest and related charges									0		0		0
Income tax expense									0		0		0
Net income (loss) attributable to Dominion									0		0		0
Capital expenditures									0		0		0
Total assets	-100				-100				-100		-100
Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
Operating Revenue	510	391	428	569	533	388	430	586	1,898	[3]	1,937	[3]	1,677	[3]
Total operating revenue									1,898		1,937		1,677
Depreciation, depletion and amortization									197		188		176
Equity in earnings of equity method investees									21		22		23
Interest income									1		2		2
Interest and related charges									27		28		40
Income tax expense									334		301		288
Net income (loss) attributable to Dominion	148	107	93	164	140	130	53	138	512		461		459
Investment in equity method affiliates	107				105				107		105
Capital expenditures									719		650		928
Total assets	9,848				9,142				9,848		9,142
Dominion Gas Holdings, LLC | Dominion Energy
Segment Reporting Information [Line Items]
Total operating revenue									1,898		1,937		1,677
Depreciation, depletion and amortization									197		188		176
Equity in earnings of equity method investees									21		22		23
Interest income									1		2		2
Interest and related charges									27		28		40
Income tax expense									340		333		293
Net income (loss) attributable to Dominion									521		510		469
Investment in equity method affiliates	107				105				107		105
Capital expenditures									719		650		928
Total assets	9,200				8,500				9,200		8,500
Dominion Gas Holdings, LLC | Corporate and Other
Segment Reporting Information [Line Items]
Total operating revenue									0		0		0
Depreciation, depletion and amortization									0		0		0
Equity in earnings of equity method investees									0		0		0
Interest income									0		0		0
Interest and related charges									0		0		0
Income tax expense									-6		-32		-5
Net income (loss) attributable to Dominion									-9		-49		-10
Investment in equity method affiliates	0				0				0		0
Capital expenditures									0		0		0
Total assets	$600				$600				$600		$600
[1]	Includes income tax benefit of $43 million and $692 million in 2013 and 2012, respectively. For 2012, includes impairment charges of $1.6 billion related to Brayton Point and Kincaid. See Note 6 for additional information.
[2]	See Note 24 for amounts attributable to affiliates.
[3]	See Note 24 for amounts attributable to related parties.

Quarterly_Financial_and_Common2

Quarterly Financial and Common Stock Data (Unaudited) (Narrative) (Details) (USD $)	3 Months Ended				12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2013	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
After tax charges associated with liability management exercise	$172
Charge recognized, net of tax		191	193
Impairment charge after tax				33
Loss from producer services business after tax				24
Brayton Point and Kincaid
Condensed Financial Statements, Captions [Line Items]
Loss before income taxes				-70
Loss from operations after tax				57
Virginia Electric and Power Company
Condensed Financial Statements, Captions [Line Items]
Charge related to settlement offer, net of tax	74
Charge recognized, net of tax		191
Restoration costs net of tax	28
Dominion Gas Holdings, LLC
Condensed Financial Statements, Captions [Line Items]
Impairment charge after tax					33
After tax gain from agreement to convey development rights	36
Impairment charge, net of tax		$33

Quarterly_Financial_and_Common3

Quarterly Financial and Common Stock Data (Unaudited) (Quarterly Financial and Common Stock Data) (Details) (USD $)	3 Months Ended																12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Operating Revenue	$2,943		$3,050		$2,813		$3,630		$3,185		$3,432		$2,980		$3,523		$12,436		$13,120		$12,835
Income from operations	638		921		394		768		804		1,034		548		930		2,721		3,316		2,858
Net income including noncontrolling interests	249		531		161		385		435		575		208		502		1,326		1,720		329
Income from continuing operations	243	[1]	529	[1]	159	[1]	379	[1]	431	[1]	592	[1]	272	[1]	494	[1]	1,310	[1]	1,789	[1]	1,427
Income (loss) from discontinued operations									0	[1]	-23	[1]	-70	[1]	1	[1]			-92	[1]
Net income (loss) attributable to Dominion	243		529		159		379		431		569		202		495		1,310		1,697		302
Income from continuing operations - basic (in dollars per share)	$0.42	[1]	$0.91	[1]	$0.27	[1]	$0.65	[1]	$0.74	[1]	$1.02	[1]	$0.47	[1]	$0.86	[1]	$2.25	[1]	$3.09	[1]	$2.49
Income (loss) from discontinued operations - basic (in dollars per share)									$0	[1]	($0.04)	[1]	($0.12)	[1]	$0	[1]	$0		($0.16)	[1]	($1.96)
Net income attributable to Dominion (in dollars per share)	$0.42		$0.91		$0.27		$0.65		$0.74		$0.98		$0.35		$0.86		$2.25		$2.93		$0.53
Income from continuing operations - diluted (in dollars per share)	$0.42	[1]	$0.90	[1]	$0.27	[1]	$0.65	[1]	$0.74	[1]	$1.02	[1]	$0.47	[1]	$0.86	[1]	$2.24	[1]	$3.09	[1]	$2.49
Income (loss) from discontinued operations - diluted (in dollars per share)									$0	[1]	($0.04)	[1]	($0.12)	[1]	$0	[1]	$0		($0.16)	[1]	($1.96)
Net income attributable to Dominion - diluted (in dollars per share)	$0.42		$0.90		$0.27		$0.65		$0.74		$0.98		$0.35		$0.86		$2.24		$2.93		$0.53
Dividends declared per common share	$0.60		$0.60		$0.60		$0.60		$0.56		$0.56		$0.56		$0.56		$2.40		$2.25		$2.11
Virginia Electric and Power Company
Condensed Financial Statements, Captions [Line Items]
Operating Revenue	1,814		2,053		1,729		1,983		1,745		2,059		1,710		1,781		7,579	[2]	7,295	[2]	7,226	[2]
Income from operations	312		594		205		613		408		679		463		530		1,724		2,080		1,992
Net income (loss) attributable to Dominion	151		314		69		324		199		387		265		287		858		1,138		1,050
Balance available for common stock	148		312		67		318		194		383		261		283		845		1,121		1,034
Dominion Gas Holdings, LLC
Condensed Financial Statements, Captions [Line Items]
Operating Revenue	510		391		428		569		533		388		430		586		1,898	[3]	1,937	[3]	1,677	[3]
Income from operations	255		177		154		265		233		217		88		224		851		762		750
Net income (loss) attributable to Dominion	$148		$107		$93		$164		$140		$130		$53		$138		$512		$461		$459
Maximum
Condensed Financial Statements, Captions [Line Items]
Share Price	$80.89		$71.62		$73.75		$72.22		$67.97		$64.04		$61.85		$58.25		$80.89		$67.97
Common stock market value (high)																	$80.89		$67.97
Minimum
Condensed Financial Statements, Captions [Line Items]
Share Price	$65.53		$64.71		$67.06		$63.14		$61.36		$55.51		$53.79		$51.92		$65.53		$61.36
Common stock market value (low)																	$63.14		$51.97
[1]	Amounts attributable to Dominion's common shareholders.
[2]	See Note 24 for amounts attributable to affiliates.
[3]	See Note 24 for amounts attributable to related parties.