Dominion Energy (D) 10-K 26 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Jan. 31, 2016	Jun. 30, 2015
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Trading Symbol	D
Entity Registrant Name	DOMINION RESOURCES INC /VA/
Entity Central Index Key	715,957
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		596,419,295
Entity Well Known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Public Float			$ 39,600,000,000
Virginia Electric and Power Company
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Trading Symbol	VEL - PE
Entity Registrant Name	VIRGINIA ELECTRIC & POWER CO
Entity Central Index Key	103,682
Current Fiscal Year End Date	--12-31
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	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Entity Registrant Name	Dominion Gas Holdings, LLC
Entity Central Index Key	1,603,291
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
Entity Well Known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Public Float			$ 0

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Operating Revenue		$ 11,683		$ 12,436		$ 13,120
Operating Expenses
Electric fuel and other energy-related purchases		2,725		3,400		3,885
Purchased electric capacity		330		361		358
Purchased gas		551		1,355		1,331
Other operations and maintenance		2,595		2,765		2,459
Depreciation, depletion and amortization		1,395		1,292		1,208
Other taxes		551		542		563
Total operating expenses		8,147		9,715		9,804
Income from operations		3,536		2,721		3,316
Other income		196		250		265
Interest and related charges		904		1,193		877
Income from continuing operations including noncontrolling interests before income taxes		2,828		1,778		2,704
Income tax expense		905		452		892
Income from continuing operations including noncontrolling interests		1,923		1,326		1,812
Income (loss) from discontinued operations	[1]	0		0		(92)
Net income including noncontrolling interests		1,923		1,326		1,720
Noncontrolling interests		24		16		23
Net income attributable to Dominion		1,899		1,310		1,697
Amounts attributable to Dominion:
Income from continuing operations, net of tax		1,899	[2]	1,310	[2]	1,789
Loss from discontinued operations, net of tax		0		0		(92)
Net income attributable to Dominion		1,899		1,310		1,697
Balance available for common stock		$ 1,923		$ 1,326		$ 1,720
Earnings Per Common Share-Basic:
Income from continuing operations (in dollars per share)		$ 3.21	[2]	$ 2.25	[2]	$ 3.09
Loss from discontinued operations (in dollars per share)		0		0		(0.16)
Net income attributable to Dominion (in dollars per share)		3.21		2.25		2.93
Earnings Per Common Share-Diluted:
Income from continuing operations (in dollars per share)		3.20	[2]	2.24	[2]	3.09
Loss from discontinued operations (in dollars per share)		0		0		(0.16)
Net income attributable to Dominion (in dollars per share)		3.20		2.24		2.93
Dividends declared per common share		$ 2.59		$ 2.40		$ 2.25
Virginia Electric and Power Company
Operating Revenue	[3]	$ 7,622		$ 7,579		$ 7,295
Operating Expenses
Electric fuel and other energy-related purchases	[3]	2,320		2,406		2,304
Purchased electric capacity		330		360		358
Affiliated suppliers		279		286		290
Other		1,355		1,630		1,161
Depreciation, depletion and amortization		953		915		853
Other taxes		264		258		249
Total operating expenses		5,501		5,855		5,215
Income from operations		2,121		1,724		2,080
Other income		68		93		86
Interest and related charges		443		411		369
Income from continuing operations including noncontrolling interests before income taxes		1,746		1,406		1,797
Income tax expense		659		548		659
Net income attributable to Dominion		1,087		858		1,138
Amounts attributable to Dominion:
Net income attributable to Dominion		1,087		858		1,138
Preferred dividends	[4]	0		13		17
Balance available for common stock		1,087		845		1,121
Dominion Gas Holdings, LLC
Operating Revenue	[5]	1,716		1,898		1,937
Operating Expenses
Purchased gas	[5]	133		315		323
Other energy-related purchases		21		40		93
Affiliated suppliers		64		64		70
Other	[6]	326		274		353
Depreciation, depletion and amortization		217		197		188
Other taxes		166		157		148
Total operating expenses		927		1,047		1,175
Income from operations		789		851		762
Other income		24		22		28
Interest and related charges	[5]	73		27		28
Income from continuing operations including noncontrolling interests before income taxes		740		846		762
Income tax expense		283		334		301
Net income attributable to Dominion		457		512		461
Amounts attributable to Dominion:
Net income attributable to Dominion		$ 457		$ 512		$ 461
[1]	Includes income tax benefit of $43 million in 2013.
[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 and $122 million in 2014 and 2013, respectively. See Note 9 for more information.

Consolidated Statements of Inc3

Consolidated Statements of Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income tax benefit			$ 43
Virginia Electric and Power Company
Issuance expenses related to redemption of preferred stock	$ 2
Dominion Gas Holdings, LLC | Affiliated Entity
Gain on sale of assets		$ 59	$ 122

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net income including noncontrolling interests	$ 1,923	$ 1,326	$ 1,720
Net income attributable to Dominion	1,899	1,310	1,697
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	110	17	(243)
Changes in unrealized net gains (losses) on investment securities, net of tax	6	128	203
Changes in net unrecognized pension and other postretirement benefit costs, net of tax	(66)	(305)	516
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	(108)	93	77
Net realized gains on investment securities, net of tax	(50)	(54)	(55)
Net pension and other postretirement benefit costs, net of tax	51	33	55
Changes in other comprehensive loss from equity method investees, net of tax	(1)	(4)	0
Other comprehensive income (loss)	(58)	(92)	553
Comprehensive income including noncontrolling interests	1,865	1,234	2,273
Comprehensive income attributable to noncontrolling interests	24	16	23
Comprehensive income	1,841	1,218	2,250
Virginia Electric and Power Company
Net income attributable to Dominion	1,087	858	1,138
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	(1)	(4)	6
Changes in unrealized net gains (losses) on investment securities, net of tax	(4)	15	20
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	1	(3)	0
Net realized gains on investment securities, net of tax	(6)	(6)	(3)
Other comprehensive income (loss)	(10)	2	23
Comprehensive income	1,077	860	1,161
Dominion Gas Holdings, LLC
Net income attributable to Dominion	457	512	461
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	6	(31)	39
Changes in net unrecognized pension and other postretirement benefit costs, net of tax	(20)	(10)	26
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities, net of tax	(3)	8	11
Net pension and other postretirement benefit costs, net of tax	4	5	6
Other comprehensive income (loss)	(13)	(28)	82
Comprehensive income	$ 444	$ 484	$ 543

Consolidated Statements of Com5

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net deferred gains (losses) on derivatives-hedging activities, tax	$ (74)	$ (20)	$ 161
Changes in unrealized net gains (losses) on investment securities, tax	23	(59)	(136)
Changes in net unrecognized pension and other postretirement benefit costs, tax	29	189	(341)
Net derivative (gains) losses-hedging activities, tax	68	(59)	(53)
Net realized (gains) losses on investment securities, tax	29	33	35
Net pension and other postretirement benefit costs, tax	(35)	(24)	(39)
Changes in other comprehensive income (loss) from equity method investees, tax	1	3	0
Virginia Electric and Power Company
Net deferred gains (losses) on derivatives-hedging activities, tax	2	2	(3)
Changes in unrealized net gains (losses) on investment securities, tax	1	(9)	(13)
Net derivative (gains) losses-hedging activities, tax	0	2	0
Net realized (gains) losses on investment securities, tax	4	4	2
Dominion Gas Holdings, LLC
Net deferred gains (losses) on derivatives-hedging activities, tax	(4)	19	(27)
Changes in net unrecognized pension and other postretirement benefit costs, tax	13	6	(18)
Net derivative (gains) losses-hedging activities, tax	3	(5)	(5)
Net pension and other postretirement benefit costs, tax	$ (3)	$ (3)	$ (4)

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Current Assets
Cash and cash equivalents		$ 607	$ 318
Customer receivables		1,200	1,514
Other receivables		169	119
Inventories:
Materials and supplies		902	923
Fossil fuel		381	413
Gas stored		65	74
Derivative assets		255	536
Margin deposit assets		16	287
Prepayments		198	167
Deferred income taxes		0	800
Regulatory assets		351	347
Other		47	117
Total current assets		4,191	5,615
Investments
Nuclear decommissioning trust funds		4,183	4,196
Investment in equity method affiliates		1,320	1,081
Other		271	284
Total investments		5,774	5,561
Property, Plant and Equipment
Property, plant and equipment		57,776	51,406
Accumulated depreciation, depletion and amortization		(16,222)	(15,136)
Total property, plant and equipment, net		41,554	36,270
Deferred Charges and Other Assets
Goodwill	[1]	3,294	3,044
Pension and other postretirement benefit assets		943	956
Intangible assets, net		570	570
Regulatory assets		1,865	1,642
Other		606	669
Total deferred charges and other assets		7,278	6,881
Total assets		58,797	54,327
Current Liabilities
Securities due within one year		1,826	1,375
Short-term debt		3,509	2,775
Accounts payable		726	952
Accrued interest, payroll and taxes		515	566
Derivative liabilities		312	591
Regulatory liabilities	[2]	100	170
Other	[3]	1,232	939
Total current liabilities		8,120	7,198
Long-Term Debt
Long-term debt		20,172	18,348
Junior subordinated notes		1,358	1,374
Remarketable subordinated notes		2,086	2,083
Total long-term debt		23,616	21,805
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		7,414	7,444
Asset retirement obligations		1,887	1,633
Pension and other postretirement benefit liabilities		1,199	1,296
Regulatory liabilities		2,285	1,991
Other		674	1,003
Total deferred credits and other liabilities		13,459	13,367
Total liabilities		$ 45,195	$ 42,370
Commitments and Contingencies (see Note 22)
Equity
Common stock-no par	[4]	$ 6,680	$ 5,876
Retained earnings		6,458	6,095
Accumulated other comprehensive loss		(474)	(416)
Total common shareholders' equity		12,664	11,555
Noncontrolling interests		938	402
Total equity		13,602	11,957
Total liabilities and equity		58,797	54,327
Virginia Electric and Power Company
Current Assets
Cash and cash equivalents		18	15
Customer receivables		822	986
Other receivables		109	64
Affiliated receivables		296	1
Inventories:
Materials and supplies		502	455
Fossil fuel		371	398
Margin deposit assets			6
Prepayments	[5]	38	252
Deferred income taxes		0	6
Regulatory assets		326	298
Other	[5]	22	76
Total current assets		2,504	2,551
Investments
Nuclear decommissioning trust funds		1,945	1,930
Other		3	4
Total investments		1,948	1,934
Property, Plant and Equipment
Property, plant and equipment		37,639	35,180
Accumulated depreciation, depletion and amortization		(11,708)	(11,080)
Total property, plant and equipment, net		25,931	24,100
Deferred Charges and Other Assets
Intangible assets, net		213	205
Regulatory assets		667	439
Other	[5]	359	280
Total deferred charges and other assets		1,239	924
Total assets		31,622	29,509
Current Liabilities
Securities due within one year		476	211
Short-term debt		1,656	1,361
Accounts payable		366	458
Payables to affiliates		73	92
Affiliated current borrowings		376	427
Accrued interest, payroll and taxes	[5]	190	199
Derivative liabilities	[5]	80	60
Customer deposits		119	107
Asset retirement obligations		143	7
Regulatory liabilities		35	90
Other		216	264
Total current liabilities		3,730	3,276
Long-Term Debt
Total long-term debt		8,949	8,726
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		4,654	4,415
Asset retirement obligations		1,104	848
Pension and other postretirement benefit liabilities	[5]	316	219
Regulatory liabilities		1,929	1,683
Other	[5]	299	287
Total deferred credits and other liabilities		8,302	7,452
Total liabilities		$ 20,981	$ 19,454
Commitments and Contingencies (see Note 22)
Equity
Common stock-no par	[6]	$ 5,738	$ 5,738
Other paid-in capital		1,113	1,113
Retained earnings		3,750	3,154
Accumulated other comprehensive loss		40	50
Total common shareholders' equity		10,641	10,055
Total equity		10,641	10,055
Total liabilities and equity		31,622	29,509
Dominion Gas Holdings, LLC
Current Assets
Cash and cash equivalents		13	9
Customer receivables	[7]	219	322
Other receivables	[7]	7	19
Affiliated receivables		98	12
Inventories:
Materials and supplies		54	53
Gas stored		24	12
Prepayments	[7]	88	166
Deferred income taxes		0	96
Regulatory assets		23	38
Other	[7]	40	83
Total current assets		566	810
Investments
Investment in equity method affiliates		102	107
Total investments		104	108
Property, Plant and Equipment
Property, plant and equipment		9,693	8,902
Accumulated depreciation, depletion and amortization		(2,690)	(2,538)
Total property, plant and equipment, net		7,003	6,364
Deferred Charges and Other Assets
Goodwill	[1]	542	542
Pension and other postretirement benefit assets	[7]	1,510	1,486
Intangible assets, net		83	79
Regulatory assets		449	379
Other	[7]	74	80
Total deferred charges and other assets		2,658	2,566
Total assets		10,331	9,848
Current Liabilities
Securities due within one year		400	0
Short-term debt		391	0
Accounts payable		201	247
Payables to affiliates		22	41
Affiliated current borrowings		95	384
Accrued interest, payroll and taxes	[7]	183	194
Regulatory liabilities		55	75
Other	[7]	128	97
Total current liabilities		1,475	1,038
Long-Term Debt
Total long-term debt		2,892	2,594
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,214	2,158
Regulatory liabilities		201	192
Other	[7]	231	300
Total deferred credits and other liabilities		2,646	2,650
Total liabilities		$ 7,013	$ 6,282
Commitments and Contingencies (see Note 22)
Equity
Membership interests		$ 3,417	$ 3,652
Accumulated other comprehensive loss		(99)	(86)
Total common shareholders' equity		3,318	3,566
Total liabilities and equity		$ 10,331	$ 9,848
[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]	See Note 3 for amounts attributable to related parties.
[4]	1 billion shares authorized; 596 million shares and 585 million shares outstanding at December 31, 2015 and 2014, respectively.
[5]	See Note 24 for amounts attributable to affiliates.
[6]	500,000 shares authorized; 274,723 shares outstanding at December 31, 2015 and 2014.
[7]	See Note 24 for amounts attributable to related parties.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Customer receivables (less allowance for doubtful accounts of $32 and $34)		$ 32	$ 34
Other receivables (less allowance for doubtful accounts of $2 and $3)		$ 2	$ 3
Common Stock, shares authorized		1,000,000,000	1,000,000,000
Common stock, shares outstanding		596,000,000	585,000,000
Virginia Electric and Power Company
Customer receivables (less allowance for doubtful accounts of $32 and $34)		$ 27	$ 25
Other receivables (less allowance for doubtful accounts of $2 and $3)		$ 1	$ 1
Common Stock, shares authorized		500,000	500,000
Common stock, shares outstanding		274,723	274,723
Dominion Gas Holdings, LLC
Customer receivables (less allowance for doubtful accounts of $32 and $34)	[1]	$ 1	$ 4
Other receivables (less allowance for doubtful accounts of $2 and $3)	[1]	$ 2	$ 1
[1]	See Note 24 for amounts attributable to related parties.

Consolidated Statements Equity

Consolidated Statements Equity - USD ($) shares in Millions, $ in Millions		Total	IPO	Total Common Shareholders' Equity	Total Common Shareholders' EquityIPO	Common Stock	Retained Earnings		Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests	Noncontrolling InterestsIPO	Virginia Electric and Power Company	Virginia Electric and Power CompanyCommon Stock	Virginia Electric and Power CompanyOther Paid-In Capital	Virginia Electric and Power CompanyRetained Earnings	Virginia Electric and Power CompanyAccumulated Other Comprehensive Income (Loss)	Dominion Gas Holdings, LLC	Dominion Gas Holdings, LLCMembership Interests	Dominion Gas Holdings, LLCAccumulated Other Comprehensive Income (Loss)
Beginning Balance (in shares) at Dec. 31, 2012						576							275
Beginning Balance, value at Dec. 31, 2012		$ 10,625		$ 10,568		$ 5,655	$ 5,790		$ (877)	$ 57		$ 9,233	$ 5,738	$ 1,113	$ 2,357	$ 25
Beginning Balance, value at Dec. 31, 2012																	$ 3,276	$ 3,416	$ (140)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		1,720		1,714			1,714			6		1,121
Net income attributable to Dominion		1,697										1,138			1,138		461	461
Equity contribution from parent																	6	6
Distributions																	(398)	(398)
Issuance of stock-employee and direct stock purchase plans (in shares)						4
Issuance of stock-employee and direct stock purchase plans		278		278		$ 278
Stock awards and stock options exercised (net of change in unearned compensation), value		12		12		$ 12
Other stock issuances (in shares)	[1]					1
Other stock issuances, value	[1]	7		7		$ 7
Present value of stock purchase contract payments related to RSNs	[2]	(156)		(156)		(154)	(2)
Fairless lease buyout		(72)		(15)		$ (15)				(57)
Dividends		(1,325)		(1,319)			(1,319)	[3]		(6)		(596)			(596)
Other comprehensive income (loss), net of tax		553		553					553			23				23	82		82
Beginning Balance, value at Dec. 31, 2013																	3,427	3,485	(58)
Ending Balance (shares) at Dec. 31, 2013						581							275
Beginning Balance, value at Dec. 31, 2013		11,642		11,642		$ 5,783	6,183		(324)	0		9,798	$ 5,738	1,113	2,899	48
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		1,326		1,323			1,323			3		845
Dominion Midstream's acquisition of interest in Iroquois and Issuance of Dominion Midstream common units, net of offering costs			$ 392		$ 0						$ 392
Net income attributable to Dominion		1,310										858			858		512	512
Equity contribution from parent																	1	1
Distributions																	(346)	(346)
Issuance of stock-employee and direct stock purchase plans (in shares)						3
Issuance of stock-employee and direct stock purchase plans		205		205		$ 205
Stock awards and stock options exercised (net of change in unearned compensation), value		14		14		$ 14
Other stock issuances (in shares)	[4]					1
Other stock issuances, value	[4]	14		14		$ 14
Present value of stock purchase contract payments related to RSNs	[2]	(143)		(143)		(143)
Dividends		(1,411)		(1,411)			(1,411)	[3]				(603)			(603)
Other comprehensive income (loss), net of tax		(92)		(92)					(92)			2				2	(28)		(28)
Other		10		3		$ 3				7
Beginning Balance, value at Dec. 31, 2014																	3,566	3,652	(86)
Ending Balance (shares) at Dec. 31, 2014						585							275
Beginning Balance, value at Dec. 31, 2014		11,957		11,555		$ 5,876	6,095		(416)	402		10,055	$ 5,738	1,113	3,154	50
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests		1,923		1,899			1,899			24		1,087
Dominion Midstream's acquisition of interest in Iroquois and Issuance of Dominion Midstream common units, net of offering costs		216		0						216
Acquisition of Four Brothers and Three Cedars		47		0						47
Contributions from SunEdison to Four Brothers and Three Cedars		103		0						103
Sale of interest in merchant solar projects		205		26		26				179
Purchase of Dominion Midstream common units		(25)		(6)		$ (6)				(19)
Net income attributable to Dominion		1,899										1,087			1,087		457	457
Distributions																	(692)	(692)
Issuance of stock-employee and direct stock purchase plans (in shares)						11
Issuance of stock-employee and direct stock purchase plans		786		786		$ 786
Stock awards and stock options exercised (net of change in unearned compensation), value		13		13		13
Dividends		(1,536)		(1,536)			(1,536)					(491)			(491)
Dominion Midstream distributions		(16)		0						(16)
Other comprehensive income (loss), net of tax		(58)		(58)					(58)			(10)				(10)	(13)		(13)
Other		(13)		(15)		$ (15)				2
Beginning Balance, value at Dec. 31, 2015																	$ 3,318	$ 3,417	$ (99)
Ending Balance (shares) at Dec. 31, 2015						596							275
Beginning Balance, value at Dec. 31, 2015		$ 13,602		$ 12,664		$ 6,680	$ 6,458		$ (474)	$ 938		$ 10,641	$ 5,738	$ 1,113	$ 3,750	$ 40
[1]	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.
[2]	See Note 17 for further information.
[3]	Includes subsidiary preferred dividends related to noncontrolling interests of $13 million and $17 million in 2014 and 2013, respectively.
[4]	Contains shares issued in excess of principal amounts related to converted securities. See Note 17 for further information on convertible securities.

Consolidated Statements of Equi

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

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Activities
Net income including noncontrolling interests		$ 1,923	$ 1,326	$ 1,720
Net income (loss) attributable to Dominion		1,899	1,310	1,697
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)		1,669	1,560	1,390
Deferred income taxes and investment tax credits		854	449	737
Gains on the sale of assets and businesses		(123)	(220)	(122)
Charges associated with North Anna and offshore wind legislation		0	374	0
Charges associated with Liability Management Exercise		0	284	0
Charges associated with future ash pond and landfill closure costs		99	121	0
Other adjustments		(42)	(113)	(86)
Changes in:
Accounts receivable		294	131	(98)
Inventories		(26)	(43)	(29)
Deferred fuel and purchased gas costs, net		94	(180)	102
Prepayments		(25)	24	123
Accounts payable		(199)	(202)	50
Accrued interest, payroll and taxes		(52)	(41)	(27)
Margin deposit assets and liabilities		237	361	(414)
Other operating assets and liabilities		(228)	(392)	87
Net cash provided by operating activities		4,475	3,439	3,433
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(5,575)	(5,345)	(4,065)
Acquisition of solar development projects		(418)	(206)	(39)
Acquisition of DCG		(497)	0	0
Proceeds from sales of securities		1,340	1,235	1,476
Purchases of securities		(1,326)	(1,241)	(1,493)
Proceeds from the sale of Brayton Point, Kincaid and equity method investment in Elwood		0	0	465
Proceeds from the sale of electric retail energy marketing business		0	187	0
Proceeds from Blue Racer		0	85	160
Proceeds from assignments of shale development rights		79	60	18
Other		(106)	44	20
Net cash used in investing activities		(6,503)	(5,181)	(3,458)
Financing Activities
Issuance (repayment) of short-term debt, net		734	848	(485)
Issuance of short-term notes		600	400	400
Repayment of short-term notes		(400)	(400)	(400)
Issuance and remarketing of long-term debt		2,962	6,085	4,135
Repayment and repurchase of long-term debt, including redemption premiums		(892)	(3,993)	(1,245)
Repayment of long-term debt		0	0	(258)
Acquisition of Juniper noncontrolling interest in Fairless		0	0	(923)
Net proceeds from issuance of Dominion Midstream common units		0	392	0
Contributions from SunEdison to Four Brothers and Three Cedars		103	0	0
Proceeds from sale of interest in merchant solar projects		184	0	0
Subsidiary preferred stock redemption		0	(259)	0
Issuance of common stock		786	205	278
Common dividend payments		(1,536)	(1,398)	(1,302)
Subsidiary preferred dividend payments		0	(11)	(17)
Other		(224)	(125)	(90)
Net cash provided by financing activities		2,317	1,744	93
Increase in cash and cash equivalents		289	2	68
Cash and cash equivalents at beginning of year		318	316	248
Cash and cash equivalents at end of year		607	318	316
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts		843	889	852
Income taxes		75	72	56
Significant noncash investing activities:
Accrued capital expenditures		478	315	375
Dominion Midstream's acquisition of a noncontrolling partnership interest in Iroquois in exchange for issuance of Dominion Midstream common units
Significant noncash investing activities:
Dominion Midstream's acquisition of a noncontrolling partnership interest in Iroquois in exchange for issuance of Dominion Midstream common units	[1]	216	0	0
Virginia Electric and Power Company
Operating Activities
Net income (loss) attributable to Dominion		1,087	858	1,138
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization		953	915	853
Depreciation, depletion and amortization (including nuclear fuel)		1,121	1,090	1,016
Deferred income taxes and investment tax credits		251	396	240
Charges associated with North Anna and offshore wind legislation		0	374	0
Charges associated with future ash pond and landfill closure costs		99	121	0
Other adjustments		(27)	(35)	(68)
Changes in:
Accounts receivable		128	(27)	(124)
Affiliated accounts receivable and payable		(314)	23	3
Inventories		(20)	(45)	(19)
Deferred fuel and purchased gas costs, net		64	(191)	93
Prepayments		214	(220)	(9)
Accounts payable		(75)	5	15
Accrued interest, payroll and taxes		(9)	(19)	14
Other operating assets and liabilities		36	(82)	30
Net cash provided by operating activities		2,555	2,248	2,329
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(2,474)	(2,911)	(2,394)
Acquisition of solar development projects		(43)	0	0
Purchases of nuclear fuel		(172)	(196)	(139)
Purchases of securities		(651)	(574)	(603)
Proceeds from sales of securities		639	549	572
Other		(87)	(2)	(37)
Net cash used in investing activities		(2,788)	(3,134)	(2,601)
Financing Activities
Issuance (repayment) of short-term debt, net		295	519	(151)
Issuance (repayment) of affiliated current borrowings, net		(51)	330	(338)
Issuance and remarketing of long-term debt		1,112	950	1,835
Repayment of long-term debt		(625)	(61)	(470)
Subsidiary preferred stock redemption		0	(259)	0
Common dividend payments		(491)	(590)	(579)
Subsidiary preferred dividend payments		0	(11)	(17)
Other		(4)	7	(20)
Net cash provided by financing activities		236	885	260
Increase in cash and cash equivalents		3	(1)	(12)
Cash and cash equivalents at beginning of year		15	16	28
Cash and cash equivalents at end of year		18	15	16
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts		422	383	328
Income taxes		517	386	427
Significant noncash investing activities:
Accrued capital expenditures		169	181	276
Dominion Gas Holdings, LLC
Operating Activities
Net income (loss) attributable to Dominion		457	512	461
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization		217	197	188
Deferred income taxes and investment tax credits		163	216	102
Gains on the sale of assets and businesses		(123)	(124)	(122)
Other adjustments		16	2	(3)
Changes in:
Accounts receivable		115	(42)	(17)
Affiliated receivables		(86)	(1)	2
Inventories		(13)	(2)	0
Prepayments		99	(99)	13
Accounts payable		(51)	(35)	62
Payables to affiliates		(19)	(4)	8
Accrued interest, payroll and taxes		(11)	(15)	48
Other operating assets and liabilities		(136)	(134)	(44)
Net cash provided by operating activities		628	471	698
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(795)	(719)	(650)
Proceeds from sale of assets to an affiliate		0	47	113
Advances to affiliate, net		0	0	(5)
Proceeds from Blue Racer		0	1	78
Proceeds from assignments of shale development rights		79	60	18
Other		(11)	(5)	(14)
Net cash used in investing activities		(727)	(616)	(460)
Financing Activities
Issuance (repayment) of short-term debt, net		391	0	0
Issuance (repayment) of affiliated current borrowings, net		(289)	(892)	(545)
Issuance and remarketing of long-term debt		700	1,400	1,200
Repayment of long-term debt		0	0	(569)
Distribution payments to parent		(692)	(346)	(318)
Other		(7)	(16)	(10)
Net cash provided by financing activities		103	146	(242)
Increase in cash and cash equivalents		4	1	(4)
Cash and cash equivalents at beginning of year		9	8	12
Cash and cash equivalents at end of year		13	9	8
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts		70	23	31
Income taxes		98	266	148
Significant noncash investing activities:
Accrued capital expenditures		57	35	42
Extinguishment of affiliated long-term debt in exchange for assets sold to affiliate		0	67	0
Distribution of non-cash asset (account receivable) to parent		0	0	80
Proceeds from sale of assets to affiliate not yet received		$ 0	$ 0	$ 30
[1]	See Note 3 for noncash activities related to the acquisition of Four Brothers and Three Cedars.

Nature of Operations

Nature of Operations	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	N ATURE OF O PERATIONS 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. At December 31, 2015, Dominion owns the general partner and 64.1% of the limited partner interests in Dominion Midstream, which owns a preferred equity interest and the general partner interest in Cove Point, DCG and a 25.93% noncontrolling partnership interest in Iroquois. 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 Notes 3 and 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 Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Significant Accounting Policies	S IGNIFICANT A CCOUNTING P OLICIES 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 and non-wholly-owned entities in which they have a controlling financial interest. For certain partnership structures, income is allocated based on the liquidation value of the underlying contractual arrangements. SunEdison’s ownership interest in Four Brothers and Three Cedars, as well as Terra Nova Renewable Partners' 33% interest in certain of Dominion's merchant solar projects, is reflected as noncontrolling interest in Dominion’s Consolidated Financial Statements. See Note 3 for further information on transactions with SunEdison. 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 2014 and 2013 Consolidated Financial Statements and footnotes have been reclassified to conform to the 2015 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, 2015 and 2014 included $462 million and $564 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, 2015 and 2014 included $333 million and $407 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, 2015 and 2014 included $98 million and $127 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 FERC-regulated sales of gathering, transmission, distribution and storage services. Also included are state-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 FERC-regulated sales of gathering, transmission and storage services. Also included are state-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. 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. Current income taxes are based on taxable income or loss and credits determined on a separate company basis. Under the agreements, if a subsidiary incurs a tax loss or earns a credit, recognition of current income tax benefits is limited to refunds of prior year taxes obtained by the carryback of the net operating loss or credit or to the extent the tax loss or credit is absorbed by the taxable income of other Dominion consolidated group members. Otherwise, the net operating loss or credit 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 2015, 2014 and 2013. At December 31, 2015, Virginia Power's Consolidated Balance Sheet included a $296 million affiliated receivable, representing current year excess federal income tax payments expected to be refunded, $9 million of federal income taxes payable for prior years, less than $1 million of state income taxes payable, $10 million of state income taxes receivable, $14 million of noncurrent state income taxes receivable and $2 million of noncurrent state income taxes payable. 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. In March 2015, Virginia Power received a $229 million refund of its 2014 federal income tax payments. At December 31, 2015, Dominion Gas' Consolidated Balance Sheet included $91 million of affiliated receivables, representing current year excess federal income tax payments expected to be refunded and the benefit of utilizing a subsidiary’s tax loss to offset taxable income in Dominion’s consolidated tax return to be filed in 2016, less than $1 million of state income taxes payable, $4 million of state income taxes receivable and $22 million of noncurrent 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. In March 2015, Dominion Gas received a $93 million refund of its 2014 federal income tax payments. 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, 2015 2014 (millions) Dominion $27 $42 Virginia Power 11 20 Dominion Gas 7 9 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 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 $16 million and $287 million associated with cash collateral at December 31, 2015 and 2014, respectively. Dominion's margin liabilities associated with cash collateral at December 31, 2015 were immaterial. Dominion had margin liabilities of $34 million associated with cash collateral at December 31, 2014. Virginia Power did not have any margin assets associated with cash collateral at December 31, 2015. Virginia Power had margin assets of $6 million associated with cash collateral at December 31 2014. Virginia Power did not have any margin liabilities associated with cash collateral at December 31, 2015 or 2014. Dominion Gas did not have any margin assets or liabilities related to cash collateral at December 31, 2015 or 2014. 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 and interest 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. D ERIVATIVE I NSTRUMENTS D ESIGNATED AS H EDGING I NSTRUMENTS 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 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 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 2015, 2014 and 2013, Dominion capitalized interest costs and AFUDC to property, plant and equipment of $100 million , $80 million and $66 million , respectively. In 2015, 2014 and 2013, Virginia Power capitalized AFUDC to property, plant and equipment of $30 million , $39 million and $33 million , respectively. In 2015, 2014 and 2013, Dominion Gas capitalized AFUDC to property, plant and equipment of $1 million , $1 million and $5 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 2015, 2014 and 2013, Virginia Power recorded $19 million , $8 million and $32 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, 2015 2014 2013 (percent) Dominion Generation 2.78 2.66 2.71 Transmission 2.42 2.38 2.36 Distribution 3.11 3.12 3.13 Storage 2.42 2.39 2.43 Gas gathering and processing 3.19 2.81 2.39 General and other 3.67 3.62 3.82 Virginia Power Generation 2.78 2.66 2.71 Transmission 2.33 2.34 2.28 Distribution 3.33 3.34 3.33 General and other 3.40 3.29 3.51 Dominion Gas Transmission 2.46 2.40 2.43 Distribution 2.45 2.47 2.50 Storage 2.44 2.40 2.43 Gas gathering and processing 3.20 2.82 2.39 General and other 4.72 5.77 5.93 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, 2015, 2014 and 2013. 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. 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. Additionally, Virginia Power reports accretion of AROs and depreciation on asset retirement costs associated with certain prospective rider projects as an adjustment to the regulatory asset for certain jurisdictions. Accretion of all other AROs and depreciation of all other asset retirement costs are reported in other operations and maintenance expense and depreciation expense, respectively, 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. Amortization of the issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt securities prior to stated maturity dates are generally recognized and recorded in interest expense immediately. Effective January 2016, deferred debt issuance costs will be recorded as a reduction in long-term debt in the Consolidated Balance Sheets. 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 M ARKETABLE E QUITY AND D EBT S ECURITIES 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

Acquisitions and Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2015
Business Combinations, Discontinued Operations and Disposal Groups [Abstract]
Acquisitions and Dispositions	A CQUISITIONS AND D ISPOSITIONS Dominion Proposed Acquisition of Questar Pursuant to the terms of the Questar Combination announced in February 2016, upon closing, each share of Questar common stock issued and outstanding immediately prior to the closing will be converted automatically into the right to receive $25 in cash per share, or approximately $4.4 billion in total. In addition, Questar’s debt, which currently totals approximately $1.6 billion is expected to remain outstanding. Additionally, Dominion entered into agreements with several of its lending banks pursuant to which they have committed to provide temporary debt financing consisting of a $3.9 billion acquisition facility. Dominion intends to permanently finance the transaction in a manner that supports its existing credit ratings targets by issuing a combination of common stock, mandatory convertibles (including RSNs) and debt at Dominion, and indirectly through an issuance of common units at Dominion Midstream, the proceeds of which will be applied to pay Dominion for certain assets of Questar, which are expected to be contributed to Dominion Midstream. The transaction requires approval of Questar’s shareholders and clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. Questar and Dominion also will file for review and approval, as required, from the Utah Public Service Commission and the Wyoming Public Service Commission, and provide information regarding the transaction to the Idaho Public Utilities Commission. In February 2016, the Federal Trade Commission granted antitrust approval of the Questar Combination under the Hart-Scott-Rodino Act. The Questar Combination contains certain termination rights for both Dominion and Questar, and provides that, upon termination of the Questar Combination under specified circumstances, Dominion would be required to pay a termination fee of $154 million to Questar and Questar would be required to pay Dominion a termination fee of $99 million . Subject to receipt of Questar shareholder and any required regulatory approvals and meeting closing conditions, Dominion targets closing by the end of 2016. Wholly-Owned Merchant Solar Projects Acquisitions The following table presents significant completed acquisitions of wholly-owned merchant solar projects by Dominion in 2014 and 2015. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for all of the projects. Dominion has claimed and/or expects to claim federal investment tax credits on the projects. These projects are included in the Dominion Generation operating segment. Completed Acquisition Date Seller Number of Projects Project Location Project Name(s) Initial Acquisition Cost (millions) (1) Project Cost (millions) (2) Date of Commercial Operations MW Capacity March 2014 Recurrent Energy Development Holdings, LLC 6 California Camelot, Kansas, Kent South, Old River One, Adams East, Columbia 2 $ 50 $ 428 Fourth quarter 2014 139 November 2014 CSI Project Holdco, LLC 1 California West Antelope 79 79 November 2014 20 December 2014 EDF Renewable Development, Inc. 1 California CID 71 71 January 2015 20 April 2015 EC&R NA Solar PV, LLC 1 California Alamo 66 66 May 2015 20 April 2015 EDF Renewable Development, Inc. 3 California Cottonwood (3) 106 106 May 2015 24 June 2015 EDF Renewable Development, Inc. 1 California Catalina 2 68 68 July 2015 18 July 2015 SunPeak Solar, LLC 1 California Imperial Valley 2 42 71 August 2015 20 November 2015 EC&R NA Solar PV, LLC 1 California Maricopa West 65 65 December 2015 20 November 2015 Community Energy, Inc. 1 Virginia Eastern Shore Solar 34 212 October 2016 80 (1) The purchase price was primarily allocated to Property, Plant and Equipment. (2) Includes acquisition cost. (3) One of the projects, Marin Carport, is expected to begin commercial operations in 2016. Sale of Interest in Merchant Solar Projects In September 2015, Dominion signed an agreement to sell a noncontrolling interest (consisting of 33% of the equity interests) in all of its then currently wholly-owned merchant solar projects, 24 solar projects totaling approximately 425 MW, to SunEdison for approximately $300 million . In December 2015, the sale of interest in 15 of the solar projects closed for $184 million with the sale of interest in the remaining projects completed in January 2016. SunEdison subsequently sold its interest in these projects to Terra Nova Renewable Partners. SunEdison has a future option to buy all or a portion of Dominion's remaining 67% ownership in the projects upon the occurrence of certain events, none of which had occurred as of December 31, 2015 nor are expected to occur in 2016. Non-Wholly-Owned Merchant Solar Projects Acquisitions of Four Brothers and Three Cedars In June 2015, Dominion acquired 50% of the units in Four Brothers from SunEdison for $64 million of consideration, consisting of $ 2 million in cash and a $62 million payable. As of December 31, 2015, a $43 million payable is included in other current liabilities in Dominion's Consolidated Balance Sheets. Four Brothers' purpose is to develop and operate four solar projects located in Utah, which will produce and sell electricity and renewable energy credits. The projects are expected to cost approximately $730 million to construct, including the initial acquisition cost. Dominion is obligated to contribute $445 million of capital to fund the construction of the projects and had contributed $138 million through December 31, 2015. The facilities are expected to begin commercial operations in the third quarter of 2016, generating approximately 320 MW. In September 2015, Dominion acquired 50% of the units in Three Cedars from SunEdison for $43 million of consideration, consisting of $6 million in cash and a $37 million payable. As of December 31, 2015, a $29 million payable is included in other current liabilities in Dominion’s Consolidated Balance Sheets. Three Cedars’ purpose is to develop and operate three solar projects located in Utah, which will produce and sell electricity and renewable energy credits. The projects are expected to cost approximately $425 million to construct. Dominion is obligated to contribute $276 million of capital to fund the construction of the projects and had contributed $60 million through December 31, 2015. The facilities are expected to begin commercial operations in the third quarter of 2016, generating approximately 210 MW. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for both Four Brothers and Three Cedars. Dominion expects to claim 99% of the federal investment tax credits on the projects. Dominion owns 50% of the voting interests in Four Brothers and Three Cedars and has a controlling financial interest over the entities through its rights to control operations. The allocation of the $64 million purchase price for Four Brothers resulted in $89 million of property, plant and equipment and $25 million of noncontrolling interest. The allocation of the $43 million purchase price for Three Cedars resulted in $65 million of property, plant and equipment and $22 million of noncontrolling interest. The noncontrolling interest for each entity was measured at fair value using the discounted cash flow method, with the primary components of the valuation being future cash flows (both incoming and outgoing) and the discount rate. Dominion determined its discount rate based on the cost of capital a utility-scale investor would expect, as well as the cost of capital an individual project developer could achieve via a combination of non-recourse project financing and outside equity partners. The acquired assets of Four Brothers and Three Cedars are included in the Dominion Generation operating segment. Four Brothers and Three Cedars have entered into agreements with SunEdison to provide administrative and support services in connection with the construction of the projects, operation and maintenance of the facilities, and administrative and technical management services of the solar facilities. In addition, Dominion has entered into contracts with SunEdison to provide services related to construction project management and oversight. Costs related to services to be provided under these agreements were immaterial for the year ended December 31, 2015. Subsequent to Dominion’s acquisition of Four Brothers and Three Cedars through December 31, 2015, SunEdison made contributions to Four Brothers and Three Cedars of $103 million in aggregate, which are reflected as noncontrolling interests in the Consolidated Balance Sheets. In December 2015, SunEdison entered an agreement to sell its interest in Four Brothers and Three Cedars through the sale of Four Brothers Holdings, LLC, Granite Mountain Renewables, LLC and Iron Springs Renewables, LLC to DESRI. Dominion Midstream Acquisition of Interest in Iroquois In September 2015, Dominion Midstream acquired from NG and NJNR a 25.93% noncontrolling partnership interest in Iroquois, which owns and operates a 416 -mile, FERC-regulated natural gas transmission pipeline in New York and Connecticut. In exchange for this partnership interest, Dominion Midstream issued 8.6 million common units representing limited partnership interests in Dominion Midstream ( 6.8 million common units to NG for its 20.4% interest and 1.8 million common units to NJNR for its 5.53% interest). The investment was recorded at $216 million based on the value of Dominion Midstream's common units at closing. These common units are reflected as noncontrolling interest in Dominion's Consolidated Financial Statements. Dominion Midstream's noncontrolling partnership interest is reflected in the Dominion Energy operating segment. In addition to this acquisition, Dominion Gas currently holds a 24.72% noncontrolling partnership interest in Iroquois. Dominion Midstream and Dominion Gas each account for their interest in Iroquois as an equity method investment. See Notes 9 and 15 for more information regarding Iroquois. Acquisition of DCG In January 2015, Dominion completed the acquisition of 100% of the equity interests of DCG from SCANA Corporation for $497 million in cash, as adjusted for working capital. DCG 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 southeastern U.S. The allocation of the purchase price resulted in $277 million of net property, plant and equipment, $250 million of goodwill, of which approximately $225 million is expected to be deductible for income tax purposes, and $38 million of regulatory liabilities. The goodwill reflects the value associated with enhancing Dominion's regulated gas position, economic value attributable to future expansion projects as well as increased opportunities for synergies. The acquired assets of DCG are included in the Dominion Energy operating segment. On March 24, 2015, DCG converted to a limited liability company under the laws of South Carolina and changed its name from Carolina Gas Transmission Corporation to DCG. On April 1, 2015, Dominion contributed 100% of the issued and outstanding membership interests of DCG to Dominion Midstream in exchange for total consideration of $501 million , as adjusted for working capital. Total consideration to Dominion consisted of the issuance of a two -year, $301 million senior unsecured promissory note payable by Dominion Midstream at an annual interest rate of 0.6% , and 5,112,139 common units, valued at $200 million , representing limited partner interests in Dominion Midstream. The number of units was based on the volume weighted average trading price of Dominion Midstream's common units for the ten trading days prior to April 1, 2015, or $39.12 per unit. Since Dominion consolidates Dominion Midstream for financial reporting purposes, this transaction was eliminated upon consolidation and did not impact Dominion's financial position or cash flows. Sale of Electric Retail Energy Marketing Business In March 2014, Dominion completed the sale of its electric retail energy marketing business. The proceeds were $187 million , net of transaction costs. The sale resulted in a gain, subject to post-closing adjustments, of $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 $32 million , subject to post-closing adjustments. The sale resulted in a gain of $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 $465 million , net of transaction costs. The sale resulted in a $35 million ( $25 million after-tax) gain attributable to its equity method investment in Elwood, which is included in other income in Dominion's Consolidated Statement of Income, which was partially offset by a $17 million ( $18 million after-tax) loss attributable to Brayton Point and Kincaid, which includes a $16 million write-off of goodwill and is reflected in loss from discontinued operations in Dominion's Consolidated Statement of Income. The following table presents selected information regarding the results of operations of Brayton Point and Kincaid, which are reported as discontinued operations in Dominion's Consolidated Statements of Income: Year Ended December 31, 2013 (millions) Operating revenue $ 304 Loss before income taxes (135 ) (1) (1) Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013. Virginia Power Acquisition of Solar Project In December 2015, Virginia Power completed the acquisition of 100% of a solar development project in North Carolina from Morgans Corner for $47 million , all of which was allocated to property, plant and equipment. The project was placed into service in December 2015 with a total cost of $49 million , including the initial acquisition cost. The project generates approximately 20 MW. The output generated by the project will be used to meet a ten year non-jurisdictional supply agreement with the U.S. Navy, which has the unilateral option to extend for an additional ten years. In October 2015, the North Carolina Commission granted the transfer of the existing CPCN from Morgans Corner to Virginia Power. The acquired asset is included in the Virginia Power Generation operating segment. Dominion and Dominion Gas Blue Racer See Note 9 for a discussion of transactions related to Blue Racer. Assignments of Shale Development Rights See Note 10 for a discussion of assignments of shale development rights.

Operating Revenue

Operating Revenue	12 Months Ended
	Dec. 31, 2015
Regulated and Unregulated Operating Revenue [Abstract]
Operating Revenue	O PERATING R EVENUE The Companies' operating revenue consists of the following: Year Ended December 31, 2015 2014 2013 (millions) Dominion Electric sales: Regulated $ 7,482 $ 7,460 $ 7,193 Nonregulated 1,488 1,839 2,511 Gas sales: Regulated 218 334 323 Nonregulated 471 751 930 Gas transportation and storage 1,616 1,543 1,535 Other 408 509 628 Total operating revenue $ 11,683 $ 12,436 $ 13,120 Virginia Power Regulated electric sales $ 7,482 $ 7,460 $ 7,193 Other 140 119 102 Total operating revenue $ 7,622 $ 7,579 $ 7,295 Dominion Gas Gas sales: Regulated $ 122 $ 209 $ 202 Nonregulated 10 26 32 Gas transportation and storage 1,366 1,353 1,338 NGL revenue 93 212 292 Other 125 98 73 Total operating revenue $ 1,716 $ 1,898 $ 1,937

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	I NCOME T AXES 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 2015, U.S. federal legislation was enacted, providing an extension of the 50% bonus depreciation allowance for qualifying expenditures incurred in 2015, 2016 and 2017, and a phasing down of the allowance to 40% in 2018 and 30% in 2019 and expiration thereafter. In addition, the legislation extends the 30% investment tax credit for qualifying expenditures incurred through 2019 and provides a phase down of the credit to 26% in 2020, 22% in 2021 and 10% in 2022 and thereafter. U.S. federal legislation had also been enacted in December 2014 to delay the expiration of the bonus depreciation allowance, but only for one year, so that it was available for qualifying expenditures incurred during 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, 2015 2014 2013 2015 2014 2013 2015 2014 2013 (millions) Current: Federal $ (24 ) $ (11 ) $ 317 $ 316 $ 85 $ 357 $ 90 $ 86 $ 158 State 75 14 110 92 67 62 30 32 41 Total current expense 51 3 427 408 152 419 120 118 199 Deferred: Federal Taxes before operating loss carryforwards and investment tax credits 384 956 563 154 381 224 156 192 92 Tax utilization (benefit) of operating loss carryforwards 539 (352 ) (18 ) 96 — — 6 — — Investment tax credits (134 ) (152 ) (48 ) (11 ) — — — — — State 66 (2 ) (31 ) 13 16 17 1 24 10 Total deferred expense 855 450 466 252 397 241 163 216 102 Amortization of deferred investment tax credits (1 ) (1 ) (1 ) (1 ) (1 ) (1 ) — — — Total income tax expense $ 905 $ 452 $ 892 $ 659 $ 548 $ 659 $ 283 $ 334 $ 301 In 2015, Dominion’s current federal income tax benefit includes the recognition of a $20 million benefit related to a carryback to be filed for nuclear decommissioning expenditures included in its 2014 net operating loss. 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, 2015 2014 2013 2015 2014 2013 2015 2014 2013 U.S. statutory rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 3.7 — 2.1 3.9 3.8 3.1 2.7 4.4 4.3 Investment tax credits (4.7 ) (8.6 ) (1.8 ) (0.6 ) — — — — — Production tax credits (0.8 ) (1.2 ) (0.6 ) (0.6 ) (0.6 ) (0.2 ) — — — Valuation allowances (0.3 ) 0.7 (0.1 ) — — — — — — AFUDC - equity (0.3 ) — (0.6 ) (0.6 ) — (0.8 ) 0.2 — (0.1 ) Employee stock ownership plan deduction (0.6 ) (0.9 ) (0.6 ) — — — — — — Other, net — 0.4 (0.4 ) 0.6 0.8 (0.4 ) 0.3 0.1 0.3 Effective tax rate 32.0 % 25.4 % 33.0 % 37.7 % 39.0 % 36.7 % 38.2 % 39.5 % 39.5 % 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. Dominion Gas’ effective tax rate in 2015 reflects a benefit resulting from the impact of changes in the allocation of income among states on existing deferred taxes. The Companies' deferred income taxes consist of the following: Dominion Virginia Power Dominion Gas At December 31, 2015 2014 2015 2014 2015 2014 (millions) Deferred income taxes: Total deferred income tax assets $ 1,152 $ 2,023 $ 164 $ 500 $ 129 $ 227 Total deferred income tax liabilities 8,552 8,663 4,805 4,915 2,343 2,289 Total net deferred income tax liabilities $ 7,400 $ 6,640 $ 4,641 $ 4,415 $ 2,214 $ 2,062 Total deferred income taxes: Plant and equipment, primarily depreciation method and basis differences $ 6,299 $ 5,895 $ 4,133 $ 3,965 $ 1,541 $ 1,417 Nuclear decommissioning 1,158 1,241 378 474 — — Deferred state income taxes 646 659 302 299 205 207 Federal benefit of deferred state income taxes (226 ) (231 ) (106 ) (105 ) (72 ) (72 ) Deferred fuel, purchased energy and gas costs (1 ) 27 (3 ) 18 1 7 Pension benefits 291 272 (99 ) (77 ) 613 567 Other postretirement benefits (15 ) (17 ) 30 13 (7 ) (12 ) Loss and credit carryforwards (1,004 ) (1,434 ) (53 ) (116 ) (4 ) (10 ) Valuation allowances 73 87 — — — — Partnership basis differences 367 304 — — 41 42 Other (188 ) (163 ) 59 (56 ) (104 ) (84 ) Total net deferred income tax liabilities $ 7,400 $ 6,640 $ 4,641 $ 4,415 $ 2,214 $ 2,062 At December 31, 2015, Dominion had the following deductible loss and credit carryforwards: • Federal loss carryforwards of $594 million that expire if unutilized during the period 2021 through 2034; • Federal investment tax credits of $407 million that expire if unutilized during the period 2033 through 2035; • Federal production and other tax credits of $89 million that expire if unutilized during the period 2031 through 2035; • State loss carryforwards of $1.6 billion that expire if unutilized during the period 2018 through 2034. A valuation allowance on $1.1 billion of these carryforwards has been established; • State minimum tax credits of $145 million that do not expire; and • State investment tax credits of $40 million that expire if unutilized during the period 2019 through 2024. At December 31, 2015, Virginia Power had the following deductible loss and credit carryforwards: • Federal loss carryforwards of $7 million that expire if unutilized during the period 2031 through 2034; • Federal investment, production and other tax credits of $38 million that expire if unutilized during the period 2031 through 2035; and • State investment tax credits of $9 million that expire if unutilized by 2024. At December 31, 2015, Dominion Gas had federal loss carryforwards of $10 million that expire if unutilized during the period 2031 through 2034 and no credit carryforwards. A reconciliation of changes in the Companies' unrecognized tax benefits follows: Dominion Virginia Power Dominion Gas 2015 2014 2013 2015 2014 2013 2015 2014 2013 (millions) Balance at January 1 $ 145 $ 222 $ 293 $ 36 $ 39 $ 57 $ 29 $ 29 $ 30 Increases-prior period positions 2 24 17 — 2 12 — — — Decreases-prior period positions (40 ) (26 ) (99 ) (25 ) (16 ) (42 ) — — (1 ) Increases-current period positions 8 16 30 1 11 14 — — — Decreases-current period positions — — (5 ) — — — — — — Settlements with tax authorities (5 ) — (2 ) — — (2 ) — — — Expiration of statutes of limitations (7 ) (91 ) (12 ) — — — — — — Balance at December 31 $ 103 $ 145 $ 222 $ 12 $ 36 $ 39 $ 29 $ 29 $ 29 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 $69 million , $77 million and $126 million at December 31, 2015, 2014 and 2013, respectively. For Dominion, the change in these unrecognized tax benefits decreased income tax expense by $6 million , $47 million and $29 million in 2015, 2014 and 2013, respectively. For Virginia Power, these unrecognized tax benefits were $8 million at December 31, 2015, 2014 and 2013. For Virginia Power, the change in these unrecognized tax benefits affected income tax expense by less than $1 million in both 2015 and 2014 and increased income tax expense by $4 million in 2013. For Dominion Gas, these unrecognized tax benefits were $19 million at December 31, 2015, 2014 and 2013. For Dominion Gas, the change in these unrecognized tax benefits affected income tax expense by less than $1 million in 2015, 2014 and 2013. 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 U.S. Congressional Joint Committee on Taxation for review. Early in 2014, Dominion received notification that the matter had been resolved with no further adjustments. Effective for its 2014 tax year, Dominion was accepted into the CAP. Through the CAP, Dominion has 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 agreed to by the IRS. Under a Pre-CAP plan, the IRS audit of tax years 2012 and 2013 began in early 2014 and concluded in late 2015. The IRS audit of CAP tax year 2014 also began in 2014. The IRS issued a partial acceptance letter in late 2015 and completed its post-filing review of the 2014 tax year in early 2016. The IRS audit of CAP tax year 2015 began in 2015. Accordingly, Dominion’s earliest tax year remaining open for federal examination is 2015. It is reasonably possible that settlement negotiations and expiration of statutes of limitations could result in a decrease in unrecognized tax benefits in 2016 by up to $30 million for Dominion and $22 million for Dominion Gas. 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 $15 million for Dominion and $10 million for Dominion Gas. Otherwise, with regard to 2015 and prior years, Dominion and Dominion Gas cannot estimate the range of reasonably possible changes to unrecognized tax benefits that may occur in 2016. After considering the possibility of potential changes in the status of its remaining unrecognized tax benefits, Virginia Power has concluded that no significant changes are reasonably possible to occur in 2016. 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 2012 Virginia (2) 2012 West Virginia (1) 2012 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 generally subject to examination. Discontinued Operations Details of income tax expense for Dominion's discontinued operations were as follows: Year Ended December 31, 2013 (millions) Current: Federal (274 ) State (41 ) Total current benefit (315 ) Deferred: Federal 232 State 40 Total deferred expense 272 Total income tax benefit (43 ) 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, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	F AIR V ALUE M EASUREMENTS 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 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, the Companies 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 derivative contracts: • Forward commodity 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, 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 price or other inputs that are considered to be unobservable are significant to 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. 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 quantitative information about Level 3 fair value measurements at December 31, 2015. 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) $ 97 Discounted Cash Flow Market Price (per Dth) (4) (2) - 8 (1 ) Credit Spread (5) 1% - 6% 3 % Liquids (3) 4 Discounted Cash Flow Market Price (per Gal) (4) 0 - 2 1 FTRs 9 Discounted Cash Flow Market Price (per MWh) (4) (2) - 14 1 Physical and Financial Options: Natural Gas 4 Option Model Market Price (per Dth) (4) 2 - 3 3 Price Volatility (6) 25% - 58% 37 % Total assets $ 114 Liabilities: Physical and Financial Forwards and Futures: Natural Gas (2) $ 9 Discounted Cash Flow Market Price (per Dth) (4) (2) - 3 2 FTRs 3 Discounted Cash Flow Market Price (per MWh) (4) (9) - 9 2 Physical and Financial Options: Natural Gas 7 Option Model Market Price (per Dth) (4) 2 - 5 3 Price Volatility (6) 25% - 58% 35 % Total liabilities $ 19 (1) Averages weighted by volume. (2) Includes basis. (3) Includes NGLs and oil. (4) Represents market prices beyond defined terms for Levels 1 and 2. (5) Represents credit spreads unrepresented in published markets. (6) Represents volatilities 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 See Note 3 for information regarding the sale of Brayton Point, Kincaid and Dominion's equity method investment in Elwood. 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. 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, 2015 Assets: Derivatives: Commodity $ 1 $ 249 $ 114 $ 364 Interest rate — 24 — 24 Investments (1) : Equity securities: U.S.: Large Cap 2,547 — — 2,547 Other 5 — — 5 REIT 63 — — 63 Non-U.S.: Large Cap 10 — — 10 Fixed Income: Corporate debt instruments — 437 — 437 U.S. Treasury securities and agency debentures 458 201 — 659 State and municipal — 376 — 376 Other — 100 — 100 Cash equivalents and other 2 2 — 4 Total assets $ 3,086 $ 1,389 $ 114 $ 4,589 Liabilities: Derivatives: Commodity $ — $ 141 $ 19 $ 160 Interest rate — 183 — 183 Total liabilities $ — $ 324 $ 19 $ 343 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 (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: 2015 2014 2013 (millions) Balance at January 1, $ 107 $ (16 ) $ 25 Total realized and unrealized gains (losses): Included in earnings (5 ) 97 (9 ) Included in other comprehensive income (loss) (9 ) 7 1 Included in regulatory assets/liabilities (4 ) 109 (9 ) Settlements 9 (88 ) (23 ) Transfers out of Level 3 (1) (3 ) (2 ) (1 ) Balance at December 31, $ 95 $ 107 $ (16 ) 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 $ 2 $ 6 $ — (1) In March 2015, Dominion changed the classification of certain short term NGL derivatives from Level 3 to Level 2 due to an increase in liquidity in financial forward markets. The transfers out of Level 3 that relate to NGLs for the year ended December 31, 2015 were $9 million . The following table presents Dominion's gains and losses included in earnings in the Level 3 fair value category: Operating Electric Fuel Purchased Total (millions) Year Ended December 31, 2015 Total gains (losses) included in earnings $ 6 $ (11 ) $ — $ (5 ) 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 — 2 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 ) — Virginia Power The following table presents Virginia Power's quantitative information about Level 3 fair value measurements at December 31, 2015. 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 $ 9 Discounted Cash Flow Market Price (per MWh) (3) (2) - 14 1 Natural gas (2) 92 Discounted Cash Flow Market Price (per Dth) (3) (2) - 4 (1 ) Credit Spread (4) 1% - 6% 3 % Total assets $ 101 Liabilities: Physical and Financial Forwards and Futures: FTRs $ 3 Discounted Cash Flow Market Price (per MWh) (3) (9) - 9 2 Physical and Financial Options: Natural gas 5 Discounted Cash Flow Market Price (per Dth) (3) 2 - 5 3 Price Volatility (5) 32% - 38% 35 % Total liabilities $ 8 (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. (5) Represents volatilities 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) 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, 2015 Assets: Derivatives: Commodity $ — $ 13 $ 101 $ 114 Interest rate — 13 — 13 Investments (1) : Equity securities: U.S.: Large Cap 1,100 — — 1,100 REIT 63 — — 63 Fixed Income: Corporate debt instruments — 238 — 238 U.S. Treasury securities and agency debentures 180 79 — 259 State and municipal — 175 — 175 Other — 34 — 34 Total assets $ 1,343 $ 552 $ 101 $ 1,996 Liabilities: Derivatives: Commodity $ — $ 19 $ 8 $ 27 Interest rate — 59 — 59 Total liabilities $ — $ 78 $ 8 $ 86 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 (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: 2015 2014 2013 (millions) Balance at January 1, $ 102 $ (7 ) $ 2 Total realized and unrealized gains (losses): Included in earnings (13 ) 96 (17 ) Included in regulatory assets/liabilities (5 ) 109 (9 ) Settlements 13 (96 ) 17 Transfers out of Level 3 (4 ) — — Balance at December 31, $ 93 $ 102 $ (7 ) The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases expense in Virginia Power's Consolidated Statements of Income for the years ended December 31, 2015, 2014 and 2013. 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, 2015, 2014 and 2013. Dominion Gas The following table presents Dominion Gas' quantitative information about Level 3 fair value measurements at December 31, 2015. 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: NGLs $ 6 Discounted Cash Flow Market Price (per Gal) (2) 0 - 1 1 Total assets $ 6 (1) Averages weighted by volume. (2) Represents market prices beyond defined terms for Levels 1 and 2. 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, 2015 Assets: Commodity $ — $ 5 $ 6 $ 11 Total assets $ — $ 5 $ 6 $ 11 Liabilities: Interest rate $ — $ 14 $ — $ 14 Total liabilities $ — $ 14 $ — $ 14 At December 31, 2014 Assets: Commodity $ — $ — $ 2 $ 2 Total assets $ — $ — $ 2 $ 2 Liabilities: Interest rate $ — $ 9 $ — 9 Total liabilities $ — $ 9 $ — $ 9 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: 2015 2014 2013 (millions) Balance at January 1, $ 2 $ (6 ) $ (12 ) Total realized and unrealized gains (losses): Included in earnings 1 2 1 Included in other comprehensive income (loss) (5 ) 10 3 Settlements (1 ) (4 ) 2 Transfers out of Level 3 (1) 9 — — Balance at December 31, $ 6 $ 2 $ (6 ) (1) In March 2015, Dominion Gas changed the classification of certain short term NGL derivatives from Level 3 to Level 2 due to an increase in liquidity in financial forward markets. The transfers out of Level 3 that relate to NGLs for the year ended December 31, 2015 were $9 million . 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, 2015, 2014 and 2013. 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, 2015, 2014 and 2013. 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, 2015 2014 Carrying Amount Estimated Fair Value (1) Carrying Amount Estimated Fair Value (1) (millions) Dominion Long-term debt, including securities due within one year (2) $ 21,998 $ 23,210 $ 19,723 $ 21,881 Junior subordinated notes (3) 1,358 1,192 1,374 1,396 Remarketable subordinated notes (3) 2,086 2,129 2,083 2,362 Virginia Power Long-term debt, including securities due within one year (3) $ 9,425 $ 10,400 $ 8,937 $ 10,293 Dominion Gas Long-term debt, including securities due within one year (3) $ 3,292 $ 3,299 $ 2,594 $ 2,672 (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, 2015, and 2014, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of $7 million and $19 million , respectively. (3) Carrying amount includes amounts which represent the unamortized discount and/or premium.

Derivatives and Hedge Accountin

Derivatives and Hedge Accounting Activities	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives and Hedge Accounting Activities	D ERIVATIVES AND H EDGE A CCOUNTING A CTIVITIES 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 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 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. Virginia Power's and 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 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: December 31, 2015 December 31, 2014 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 $ 24 $ — $ 24 Commodity contracts: Over-the-counter 217 — 217 382 — 382 Exchange 138 — 138 298 — 298 Total derivatives, subject to a master netting or similar arrangement 379 — 379 704 — 704 Total derivatives, not subject to a master netting or similar arrangement 9 — 9 15 — 15 Total $ 388 $ — $ 388 $ 719 $ — $ 719 December 31, 2015 December 31, 2014 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 $ 22 $ — $ 2 $ 24 $ 16 $ — $ 8 Commodity contracts: Over-the-counter 217 37 — 180 382 34 34 314 Exchange 138 82 — 56 298 298 — — Total $ 379 $ 141 $ — $ 238 $ 704 $ 348 $ 34 $ 322 December 31, 2015 December 31, 2014 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 $ 183 $ — $ 183 $ 202 $ — $ 202 Commodity contracts: Over-the-counter 70 — 70 87 — 87 Exchange 82 — 82 493 — 493 Total derivatives, subject to a master netting or similar arrangement 335 — 335 782 — 782 Total derivatives, not subject to a master netting or similar arrangement 8 — 8 12 — 12 Total $ 343 $ — $ 343 $ 794 $ — $ 794 December 31, 2015 December 31, 2014 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 $ 183 $ 22 $ — $ 161 $ 202 $ 16 $ — $ 186 Commodity contracts: Over-the-counter 70 37 — 33 87 34 1 52 Exchange 82 82 — — 493 298 195 — Total $ 335 $ 141 $ — $ 194 $ 782 $ 348 $ 196 $ 238 Volumes The following table presents the volume of Dominion's derivative activity as of December 31, 2015. 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) 80 19 Basis 216 554 Electricity (MWh): Fixed price 15,661,078 — FTRs 33,350,993 — Capacity (MW) 7,600 — Liquids (Gal) (2) 83,076,000 18,606,000 Interest rate $ 2,950,000,000 $ 3,100,000,000 (1) Includes options. (2) Includes NGLs and oil. Ineffectiveness and AOCI For the years ended December 31, 2015, 2014 and 2013, 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, 2015: AOCI Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax Maximum (millions) Commodities: Gas $ (7 ) $ (7 ) 22 months Electricity 76 76 12 months Other 6 6 15 months Interest rate (251 ) (9 ) 387 months Total $ (176 ) $ 66 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 (millions) At December 31, 2015 ASSETS Current Assets Commodity $ 101 $ 151 $ 252 Interest rate 3 — 3 Total current derivative assets 104 151 255 Noncurrent Assets Commodity 3 109 112 Interest rate 21 — 21 Total noncurrent derivative assets (1) 24 109 133 Total derivative assets $ 128 $ 260 $ 388 LIABILITIES Current Liabilities Commodity $ 32 $ 116 $ 148 Interest rate 164 — 164 Total current derivative liabilities 196 116 312 Noncurrent Liabilities Commodity — 12 12 Interest rate 19 — 19 Total noncurrent derivative liabilities (2) 19 12 31 Total derivative liabilities $ 215 $ 128 $ 343 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 (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 (1) Amount of Increase (2) (millions) Year Ended December 31, 2015 Derivative Type and Location of Gains (Losses) Commodity: Operating revenue $ 203 Purchased gas (15 ) Electric fuel and other energy-related purchases (1 ) Total commodity $ 230 $ 187 $ 4 Interest rate (3) (46 ) (11 ) (13 ) Total $ 184 $ 176 $ (9 ) 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 (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) Year Ended December 31, 2015 2014 2013 (millions) Derivative Type and Location of Gains (Losses) Commodity: Operating revenue $ 24 $ (310 ) $ (45 ) Purchased gas (14 ) (51 ) (9 ) Electric fuel and other energy-related purchases (14 ) 113 (29 ) Interest rate (2) (1 ) — — Total $ (5 ) $ (248 ) $ (83 ) (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: December 31, 2015 December 31, 2014 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 $ 13 $ — $ 13 $ — $ — $ — Commodity contracts: Over-the-counter 101 — 101 106 — 106 Total derivatives, subject to a master netting or similar arrangement 114 — 114 106 — 106 Total derivatives, not subject to a master netting or similar arrangement 13 — 13 7 — 7 Total $ 127 $ — $ 127 $ 113 $ — $ 113 December 31, 2015 December 31, 2014 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 $ 13 $ 10 $ — $ 3 $ — $ — $ — $ — Commodity contracts: Over-the-counter 101 3 — 98 106 4 — 102 Total $ 114 $ 13 $ — $ 101 $ 106 $ 4 $ — $ 102 December 31, 2015 December 31, 2014 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 $ 59 $ — $ 59 $ 72 $ — $ 72 Commodity contracts: Over-the-counter 5 — 5 8 — 8 Total derivatives, subject to a master netting or similar arrangement 64 — 64 80 — 80 Total derivatives, not subject to a master netting or similar arrangement 22 — 22 7 — 7 Total $ 86 $ — $ 86 $ 87 $ — $ 87 December 31, 2015 December 31, 2014 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 $ 59 $ 10 $ — $ 49 $ 72 $ — $ — $ 72 Commodity contracts: Over-the-counter 5 3 — 2 8 4 — 4 Total $ 64 $ 13 $ — $ 51 $ 80 $ 4 $ — $ 76 Volumes The following table presents the volume of Virginia Power's derivative activity at December 31, 2015. 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) 32 10 Basis 102 509 Electricity (MWh): FTRs 30,383,934 — Capacity (MW) 7,600 — Interest rate $ 900,000,000 $ 1,100,000,000 (1) Includes options. Ineffectiveness For the years ended December 31, 2015, 2014 and 2013, 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 - Derivatives under Hedge Accounting Fair Value - Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2015 ASSETS Current Assets Commodity $ — $ 18 $ 18 Total current derivative assets (1) — 18 18 Noncurrent Assets Commodity — 96 96 Interest rate 13 — 13 Total noncurrent derivative assets (2) 13 96 109 Total derivative assets $ 13 $ 114 $ 127 LIABILITIES Current Liabilities Commodity $ — $ 23 $ 23 Interest rate 57 — 57 Total current derivative liabilities 57 23 80 Noncurrent Liabilities Commodity — 4 4 Interest rate 2 — 2 Total noncurrent derivative liabilities (3) 2 4 6 Total derivative liabilities $ 59 $ 27 $ 86 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 (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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified from AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Year Ended December 31, 2015 Derivative Type and Location of Gains (Losses) Commodity: Electric fuel and other energy-related purchases $ (1 ) Total commodity $ — $ (1 ) $ 4 Interest rate (3) (3 ) — (13 ) Total $ (3 ) $ (1 ) $ (9 ) 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 (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 instruments Amount of Gain (Loss) Recognized in Income on Derivatives (1) Year Ended December 31, 2015 2014 2013 (millions) Derivative Type and Location of Gains (Losses) Commodity (2) $ (13 ) $ 105 $ (16 ) Total $ (13 ) $ 105 $ (16 ) (1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power's Consolidated Statements of Income. (2) Amounts 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: December 31, 2015 December 31, 2014 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) Commodity contracts: Over-the-counter $ 11 $ — $ 11 $ 2 $ — $ 2 Total derivatives, subject to a master netting or similar arrangement $ 11 $ — $ 11 $ 2 $ — $ 2 December 31, 2015 December 31, 2014 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) Commodity contracts: Over-the-counter $ 11 $ — $ — $ 11 $ 2 $ — $ — $ 2 Total $ 11 $ — $ — $ 11 $ 2 $ — $ — $ 2 December 31, 2015 December 31, 2014 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 $ 14 $ — $ 14 $ 9 $ — $ 9 Total derivatives, subject to a master netting or similar arrangement $ 14 $ — $ 14 $ 9 $ — $ 9 December 31, 2015 December 31, 2014 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 $ 14 $ — $ — $ 14 $ 9 $ — $ — $ 9 Total $ 14 $ — $ — $ 14 $ 9 $ — $ — $ 9 Volumes The following table presents the volume of Dominion Gas' derivative activity at December 31, 2015. 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 (Gal) 77,364,000 13,818,000 Interest rate $ 250,000,000 $ — Ineffectiveness and AOCI For the years ended December 31, 2015, 2014 and 2013, 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, 2015: AOCI Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax Maximum (millions) Commodities: NGLs $ 7 $ 6 15 months Interest rate (24 ) — 348 months Total $ (17 ) $ 6 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 - Derivatives under Hedge Accounting Fair Value - Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2015 ASSETS Current Assets Commodity $ 10 $ — $ 10 Total current derivative assets (1) 10 — 10 Noncurrent Assets Commodity 1 — 1 Total noncurrent derivative assets (2) 1 — 1 Total derivative assets $ 11 $ — $ 11 LIABILITIES Current Liabilities Interest rate $ 14 $ — $ 14 Total current derivative liabilities (3) 14 — 14 Total derivative liabilities $ 14 $ — $ 14 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 (4) 9 — 9 Total derivative liabilities $ 9 $ — $ 9 (1) Current derivative assets are presented in other current assets in Dominion Gas' Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other 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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified from AOCI to Income (millions) Year Ended December 31, 2015 Derivative Type and Location of Gains (Losses) Commodity: Operating revenue $ 6 Total commodity $ 16 $ 6 Interest rate (2) (6 ) — Total $ 10 $ 6 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 ) (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. Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized in Income on Derivatives Year Ended December 31, 2015 2014 2013 (millions) Derivative Type and Location of Gains (Losses) Commodity Operating revenue $ 6 $ — $ — Total $ 6 $ — $ —

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share	E ARNINGS P ER S HARE The following table presents the calculation of Dominion's basic and diluted EPS: 2015 2014 2013 (millions, except EPS) Net income attributable to Dominion $ 1,899 $ 1,310 $ 1,697 Average shares of common stock outstanding-Basic 592.4 582.7 578.7 Net effect of dilutive securities (1) 1.3 1.8 0.8 Average shares of common stock outstanding-Diluted 593.7 584.5 579.5 Earnings Per Common Share-Basic $ 3.21 $ 2.25 $ 2.93 Earnings Per Common Share-Diluted $ 3.20 $ 2.24 $ 2.93 (1) Dilutive securities consist primarily of the 2013 Equity Units for 2015, the 2013 Equity Units and contingently convertible senior notes for 2014, and contingently convertible senior notes for 2013. 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, 2015 as inclusion would have been antidilutive. The 2014 Equity Units 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.

Investments

Investments	12 Months Ended
	Dec. 31, 2015
Investments, Debt and Equity Securities [Abstract]
Investments	I NVESTMENTS Dominion Equity and Debt Securities Rabbi Trust Securities Marketable equity and debt securities and cash equivalents held in Dominion's rabbi trusts and classified as trading totaled $100 million and $110 million at December 31, 2015 and 2014, respectively. Decommissioning Trust Securities Dominion holds marketable equity and debt securities (classified as available-for-sale), cash equivalents and cost method investments in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Dominion's decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains (1) Total Unrealized Losses (1) Fair Value (millions) At December 31, 2015 Marketable equity securities: U.S. large cap $ 1,295 $ 1,213 $ — $ 2,508 REIT 59 4 — 63 Marketable debt securities: Corporate debt instruments 433 11 (7 ) 437 U.S. Treasury securities and agency debentures 654 8 (4 ) 658 State and municipal 312 22 — 334 Other 99 — — 99 Cost method investments 70 — — 70 Cash equivalents and other (2) 14 — — 14 Total $ 2,936 $ 1,258 $ (11 ) (3) $ 4,183 At December 31, 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 (1) Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Includes pending sales of securities of $12 million and $3 million at December 31, 2015 and 2014, respectively. (3) The fair value of securities in an unrealized loss position was $592 million and $379 million at December 31, 2015 and 2014, respectively. The fair value of Dominion's marketable debt securities held in nuclear decommissioning trust funds at December 31, 2015 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 208 Due after one year through five years 396 Due after five years through ten years 412 Due after ten years 512 Total $ 1,528 Presented below is selected information regarding Dominion's marketable equity and debt securities held in nuclear decommissioning trust funds: Year Ended December 31, 2015 2014 2013 (millions) Proceeds from sales $ 1,340 $ 1,235 $ 1,476 Realized gains (1) 219 171 157 Realized losses (1) 84 30 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, 2015 2014 2013 (millions) Total other-than-temporary impairment losses (1) $ 66 $ 21 $ 31 Losses recorded to nuclear decommissioning trust regulatory liability (26 ) (5 ) (13 ) Losses recognized in other comprehensive income (before taxes) (9 ) (3 ) (10 ) Net impairment losses recognized in earnings $ 31 $ 13 $ 8 (1) Amounts include other-than-temporary impairment losses for debt securities of $9 million , $3 million and $18 million at December 31, 2015, 2014 and 2013, 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 Cost Total Unrealized Gains (1) Total Unrealized Losses (1) Fair Value (millions) At December 31, 2015 Marketable equity securities: U.S. large cap $ 574 $ 525 $ — $ 1,099 REIT 59 4 — 63 Marketable debt securities: Corporate debt instruments 237 5 (4 ) 238 U.S. Treasury securities and agency debentures 260 1 (2 ) 259 State and municipal 162 13 (1 ) 174 Other 34 — — 34 Cost method investments 70 — — 70 Cash equivalents and other (2) 8 — — 8 Total $ 1,404 $ 548 $ (7 ) (3) $ 1,945 At December 31, 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 (1) Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Includes pending sales of securities of $8 million and $6 million at December 31, 2015 and 2014, respectively. (3) The fair value of securities in an unrealized loss position was $281 million and $170 million at December 31, 2015 and 2014, respectively. The fair value of Virginia Power's marketable debt securities at December 31, 2015, by contractual maturity is as follows: Amount (millions) Due in one year or less $ 67 Due after one year through five years 166 Due after five years through ten years 236 Due after ten years 236 Total $ 705 Presented below is selected information regarding Virginia Power's marketable equity and debt securities held in nuclear decommissioning trust funds. Year Ended December 31, 2015 2014 2013 (millions) Proceeds from sales $ 639 $ 549 $ 572 Realized gains (1) 110 73 52 Realized losses (1) 43 12 14 (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 held in nuclear decommissioning trust funds as follows: Year Ended December 31, 2015 2014 2013 (millions) Total other-than-temporary impairment losses (1) $ 36 $ 8 $ 15 Losses recorded to nuclear decommissioning trust regulatory liability (26 ) (4 ) (13 ) Losses recorded in other comprehensive income (before taxes) (6 ) (2 ) (1 ) Net impairment losses recognized in earnings $ 4 $ 2 $ 1 (1) Amounts include other-than-temporary impairment losses for debt securities of $6 million , $2 million and $9 million at December 31, 2015, 2014 and 2013, 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, 2015 2014 (millions) Dominion Blue Racer 50 % $ 661 $ 671 Midstream gas and related services Iroquois 50.65 % (1) 324 107 Gas transmission system Fowler Ridge 50 % 125 134 Wind-powered merchant generation facility NedPower 50 % 119 128 Wind-powered merchant generation facility Atlantic Coast Pipeline 45 % 59 19 Gas transmission system Other (2) various 32 22 Total $ 1,320 $ 1,081 Dominion Gas Iroquois 24.72 % $ 102 $ 107 Gas transmission system Total $ 102 $ 107 (1) Comprised of Dominion Midstream's interest of 25.93% and Dominion Gas' interest of 24.72% . See Note 15 for more information. (2) Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018. Dominion's equity earnings on its investments totaled $56 million , $46 million and $14 million in 2015, 2014 and 2013, respectively. Dominion received distributions from these investments of $83 million , $60 million and $33 million in 2015, 2014, and 2013, respectively. As of December 31, 2015 and 2014, the carrying amount of Dominion's investments exceeded its share of underlying equity in net assets by $234 million and $126 million , respectively. These differences are comprised at December 31, 2015 and 2014, of $72 million and $87 million , respectively, related 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, and $162 million and $39 million , respectively, reflecting equity method goodwill that is not being amortized. Dominion Gas' equity earnings on its investment totaled $23 million , $21 million and $22 million in 2015, 2014 and 2013, respectively. Dominion Gas received distributions from its investment of $28 million , $20 million and $19 million in 2015, 2014, and 2013, respectively. As of December 31, 2015 and 2014, the carrying amount of Dominion Gas' investment exceeded its share of underlying equity in net assets by $8 million . The difference reflects equity method goodwill and is 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 March 2013, Dominion Gas sold Line TL-404 to an affiliate, that subsequently sold line TL-404 to Blue Racer for cash proceeds of $47 million . The sale resulted in a gain of $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, Dominion Gas 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 $78 million in cash proceeds. The sales resulted in a $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, Dominion Gas sold the Western System to an affiliate, that subsequently sold the Western System to Blue Racer for cash proceeds of $30 million . The sale resulted in a gain of $3 million ( $2 million after-tax) for Dominion Gas 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 $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 $84 million . The sale resulted in a gain of $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, Piedmont and AGL, 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, 40% ; Piedmont, 10% ; and AGL, 5% . In October 2015, Duke Energy entered into a merger agreement with Piedmont. The Atlantic Coast Pipeline partnership agreement includes provisions to allow Dominion an option to purchase additional ownership interest in Atlantic Coast Pipeline to maintain a leading ownership percentage. Atlantic Coast Pipeline is focused on constructing an approximately 600 -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. Public Service Company of North Carolina, Inc. also plans to be a customer of the pipeline under a 20 -year contract. 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, 2015
Property, Plant and Equipment, Net [Abstract]
Property, Plant and Equipment	P ROPERTY , P LANT AND E QUIPMENT Major classes of property, plant and equipment and their respective balances for the Companies are as follows: At December 31, 2015 2014 (millions) Dominion Utility: Generation $ 15,656 $ 15,193 Transmission 11,461 9,897 Distribution 13,128 12,354 Storage 2,460 2,350 Nuclear fuel 1,464 1,411 Gas gathering and processing 799 791 General and other 927 845 Other-including plant under construction 5,550 3,633 Total utility 51,445 46,474 Nonutility: Merchant generation-nuclear 1,339 1,267 Merchant generation-other 2,683 2,023 Nuclear fuel 938 860 Other-including plant under construction 1,371 782 Total nonutility 6,331 4,932 Total property, plant and equipment $ 57,776 $ 51,406 Virginia Power Utility: Generation $ 15,656 $ 15,193 Transmission 6,963 5,884 Distribution 10,048 9,526 Nuclear fuel 1,464 1,411 General and other 709 697 Other-including plant under construction 2,793 2,464 Total utility 37,633 35,175 Nonutility-other 6 5 Total property, plant and equipment $ 37,639 $ 35,180 Dominion Gas Utility: Transmission $ 3,804 $ 3,690 Distribution 2,765 2,530 Storage 1,583 1,466 Gas gathering and processing 797 786 General and other 165 111 Plant under construction 443 179 Total utility 9,557 8,762 Nonutility: E&P properties being amortized and other 136 140 Total nonutility 136 140 Total property, plant and equipment $ 9,693 $ 8,902 There were no significant E&P properties under development, as defined by the SEC, excluded from Dominion Gas' amortization at December 31, 2015. 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. In 2015, Dominion Gas recorded a ceiling test impairment charge of $16 million ( $10 million after-tax) in other operations and maintenance expense in its Consolidated Statement of Income. Dominion sold substantially all its Appalachian E&P properties in April 2010, retaining only wells in and around DTI's storage facilities. The net book basis of the remaining properties as of December 31, 2015 is $14 million . Jointly-Owned Power Stations Dominion's and Virginia Power's proportionate share of jointly-owned power stations at December 31, 2015 is as follows: Bath County Pumped Storage Station (1) North Anna Units 1 and 2 (1) Clover Power Station (1) Millstone Unit 3 (2) (millions, except percentages) Ownership interest 60 % 88.4 % 50 % 93.5 % Plant in service $ 1,049 $ 2,452 $ 576 $ 1,149 Accumulated depreciation (567 ) (1,177 ) (214 ) (320 ) Nuclear fuel — 621 — 521 Accumulated amortization of nuclear fuel — (502 ) — (364 ) Plant under construction 12 116 16 55 (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 Shale Development Rights In December 2013, Dominion Gas 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 Dominion Gas, 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, Dominion Gas received approximately $100 million in cash proceeds, resulting in a $20 million ( $12 million after-tax) gain, recorded to operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. In 2014, Dominion Gas received $16 million in additional cash proceeds resulting from post-closing adjustments. At December 31, 2014, deferred revenue totaled $85 million . In March 2015, Dominion Gas and one of the natural gas producers closed on an amendment to the agreement, which included the immediate conveyance of approximately 9,000 acres of Marcellus Shale development rights and a two -year extension of the term of the original agreement. The conveyance of development rights resulted in the recognition of $43 million ( $27 million after-tax) of previously deferred revenue to operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. At December 31, 2015, deferred revenue totaled $37 million , which is expected to be recognized over the remaining term of the agreement. In November 2014, Dominion Gas 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 Dominion Gas, 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, Dominion Gas closed on the agreement and received proceeds of $60 million associated with an initial conveyance of approximately 12,000 acres, resulting in a $60 million ( $36 million after-tax) gain, recorded to operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. In March 2015, Dominion Gas conveyed to a natural gas producer approximately 11,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields and received proceeds of $27 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $27 million ( $16 million after-tax) gain, included in other operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. In September 2015, Dominion Gas closed on an agreement with a natural gas producer to convey approximately 16,000 acres of Utica and Point Pleasant Shale development rights underneath one of its natural gas storage fields. The agreement provided for a payment to Dominion Gas, subject to customary adjustments, of $52 million and an overriding royalty interest in gas produced from the acreage. In September 2015, Dominion Gas received proceeds of $52 million associated with the conveyance of the acreage, resulting in a $52 million ( $29 million after-tax) gain, included in other operations and maintenance expense in Dominion Gas’ Consolidated Statements of Income.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	G OODWILL AND I NTANGIBLE A SSETS Goodwill The changes in Dominion's and Dominion Gas' carrying amount and segment allocation of goodwill are presented below: Dominion Generation Dominion Energy DVP Corporate and Other (1) Total (millions) Dominion Balance at December 31, 2013 (2) $ 1,454 (3) $ 706 (3) $ 926 $ — $ 3,086 Asset disposition adjustment (32 ) (4) (10 ) (5) — — (42 ) Balance at December 31, 2014 (2) $ 1,422 (3) $ 696 (3) $ 926 $ — $ 3,044 DCG acquisition — 250 — — 250 Balance at December 31, 2015 (2) $ 1,422 $ 946 $ 926 $ — $ 3,294 Dominion Gas Balance at December 31, 2013 (2) $ — $ 545 $ — $ — $ 545 Asset disposition adjustment — (3 ) (5) — — (3 ) Balance at December 31, 2014 (2) $ — $ 542 $ — $ — $ 542 No events affecting goodwill — — — — — Balance at December 31, 2015 (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) Recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment. (4) See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs. (5) 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 $78 million , $71 million and $72 million for 2015, 2014 and 2013, respectively. In 2015, Dominion acquired $78 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of approximately 8 years. Amortization expense for Virginia Power's intangible assets was $25 million , $24 million and $22 million for 2015, 2014 and 2013, respectively. In 2015, Virginia Power acquired $34 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of 6 years. Dominion Gas' amortization expense for intangible assets was $18 million , $17 million and $16 million for 2015, 2014 and 2013, respectively. In 2015, Dominion Gas acquired $24 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of approximately 14 years. The components of intangible assets are as follows: At December 31, 2015 2014 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization (millions) Dominion Software, licenses and other $ 942 $ 372 $ 887 $ 317 Total $ 942 $ 372 $ 887 $ 317 Virginia Power Software, licenses and other $ 301 $ 88 $ 286 $ 81 Total $ 301 $ 88 $ 286 $ 81 Dominion Gas Software, licenses and other $ 211 $ 128 $ 192 $ 113 Total $ 211 $ 128 $ 192 $ 113 Annual amortization expense for these intangible assets is estimated to be as follows: 2016 2017 2018 2019 2020 (millions) Dominion $ 79 $ 68 $ 57 $ 47 $ 35 Virginia Power $ 25 $ 22 $ 19 $ 15 $ 9 Dominion Gas $ 18 $ 15 $ 14 $ 13 $ 13

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets and Liabilities	R EGULATORY A SSETS AND L IABILITIES Regulatory assets and liabilities include the following: At December 31, 2015 2014 (millions) Dominion Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 111 $ 79 Deferred rate adjustment clause costs (2) 90 124 Deferred nuclear refueling outage costs (3) 75 44 Unrecovered gas costs (4) 12 36 Other 63 64 Regulatory assets-current 351 347 Unrecognized pension and other postretirement benefit costs (5) 1,015 1,050 Deferred rate adjustment clause costs (2) 295 250 PJM transmission rates (6) 192 — Income taxes recoverable through future rates (7) 126 133 Derivatives (8) 110 101 Other 127 108 Regulatory assets-non-current 1,865 1,642 Total regulatory assets $ 2,216 $ 1,989 Regulatory liabilities: PIPP (9) $ 46 $ 71 Other 54 99 Regulatory liabilities-current (10) 100 170 Provision for future cost of removal and AROs (11) 1,120 1,072 Nuclear decommissioning trust (12) 804 815 Deferred cost of fuel used in electric generation (1) 97 6 Derivatives (8) 79 — Other 185 98 Regulatory liabilities-non-current 2,285 1,991 Total regulatory liabilities $ 2,385 $ 2,161 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 111 $ 79 Deferred rate adjustment clause costs (2) 80 117 Deferred nuclear refueling outage costs (3) 75 44 Other 60 58 Regulatory assets-current 326 298 Deferred rate adjustment clause costs (2) 213 179 PJM transmission rates (6) 192 — Derivatives (8) 110 101 Income taxes recoverable through future rates (7) 97 100 Other 55 59 Regulatory assets-non-current 667 439 Total regulatory assets $ 993 $ 737 Regulatory liabilities: Other $ 35 $ 90 Regulatory liabilities-current 35 90 Provision for future cost of removal (11) 890 852 Nuclear decommissioning trust (12) 804 815 Deferred cost of fuel used in electric generation (1) 97 6 Derivatives (8) 79 — Other 59 10 Regulatory liabilities-non-current 1,929 1,683 Total regulatory liabilities $ 1,964 $ 1,773 Dominion Gas Regulatory assets: Unrecovered gas costs (4) $ 11 $ 29 Deferred rate adjustment clause costs (2) 10 7 Other 2 2 Regulatory assets-current 23 38 Unrecognized pension and other postretirement benefit costs (5) 282 242 Deferred rate adjustment clause costs (2) 82 71 Income taxes recoverable through future rates (7) 20 24 Other 65 42 Regulatory assets-non-current 449 379 Total regulatory assets $ 472 $ 417 Regulatory liabilities: PIPP (9) $ 46 $ 71 Other 9 4 Regulatory liabilities-current 55 75 Provision for future cost of removal and AROs (11) 170 172 Other 31 20 Regulatory liabilities-non-current 201 192 Total regulatory liabilities $ 256 $ 267 (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. (2) 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. (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 and Dominion Gas' rate-regulated subsidiaries. (6) Reflects amount related to the PJM transmission cost allocation matter. See Note 13 for more information. (7) Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes. (8) 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. (9) 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 rate adjustment clause according to East Ohio tariff provisions. See Note 13 for more information. (10) Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets. (11) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (12) Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power’s utility nuclear generation stations, in excess of the related AROs. At December 31, 2015, $131 million of Dominion's, $100 million of Virginia Power's and $29 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, 2015
Regulatory Matters [Abstract]
Regulatory Matters	R EGULATORY M ATTERS 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, CAISO and ISO-NE wholesale markets, and to wholesale purchasers in the states of Tennessee, Georgia, California and Utah, 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 North Carolina Electric Membership Corporation filed a complaint with FERC against Virginia Power claiming that $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 held 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. PJM Transmission Rates In April 2007, FERC issued an order regarding its transmission rate design for the allocation of costs among PJM transmission customers, including Virginia Power, for transmission service provided by PJM. For new PJM-planned transmission facilities that operate at or above 500 kV, FERC established a PJM regional rate design where customers pay according to each customer's share of the region's load. For recovery of costs of existing facilities, FERC approved the existing methodology whereby a customer pays the cost of facilities located in the same zone as the customer. A number of parties appealed the order to the U.S. Court of Appeals for the Seventh Circuit. In August 2009, the court issued its decision affirming the FERC order with regard to the existing facilities, but remanded to FERC the issue of the cost allocation associated with the new facilities 500 kV and above for further consideration by FERC. On remand, FERC reaffirmed its earlier decision to allocate the costs of new facilities 500 kV and above according to the customer’s share of the region’s load. A number of parties filed appeals of the order to the U.S. Court of Appeals for the Seventh Circuit. In June 2014, the court again remanded the cost allocation issue to FERC. In December 2014, FERC issued an order setting an evidentiary hearing and settlement proceeding regarding the cost allocation issue. The hearing only concerns the costs of new facilities approved by PJM prior to February 1, 2013. Transmission facilities approved after February 1, 2013 are allocated on a hybrid cost allocation method approved by FERC and not subject to any court review. Virginia Power expects that a settlement agreement will be executed regarding this matter. Under the terms of the settlement, Virginia Power would be required to pay $200 million to PJM over the next 10 years. Although no FERC order has been issued and the expected settlement agreement has not been filed and accepted by FERC, Virginia Power believes it is probable it will be required to make payment as an outcome of the hearing and settlement proceedings. Accordingly, as of December 31, 2015, Virginia Power has recorded a contingent liability of $200 million in other deferred credits and other liabilities, which is offset by a $192 million regulatory asset for the amount that will be recovered through retail rates in Virginia. The remaining $8 million was recorded in other operations and maintenance expense in the Consolidated Statement of Income. 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, underground distribution lines, 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. 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. The legislation states that Virginia Power’s 2015 biennial review, filed in March 2015, would proceed for the sole purpose of reviewing and determining whether any refunds are due to customers based on earnings performance for generation and distribution services 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 rate adjustment clauses and requires utilities to file integrated resource plans annually rather than biennially. However, in November 2015, the Virginia Commission ordered testimony, briefs and separate bifurcated hearing in Virginia Power’s currently pending Rider B, Rider R, Rider S and Rider W cases on whether the Virginia Commission can adjust the ROE applicable to these rate adjustment clauses prior to 2017. The legislation also required Virginia Power to write-off $85 million of prior-period deferred fuel costs during the first quarter of 2015. In addition, the legislation required 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 to be in the public interest. 2015 Biennial Review Pursuant to the Regulation Act, in March 2015, Virginia Power filed its base rate case and schedules for the Virginia Commission’s 2015 biennial review of Virginia Power’s rates, terms and conditions. Per legislation enacted in February 2015, this biennial review was limited to reviewing Virginia Power’s earnings on rates for generation and distribution services for the combined 2013 and 2014 test period, and determining whether credits are due to customers in the event Virginia Power’s earnings exceeded the earnings band determined in the 2013 Biennial Review Order. In November 2015, the Virginia Commission issued the 2015 Biennial Review Order. After deciding several contested regulatory earnings adjustments, the Virginia Commission ruled that Virginia Power earned on average an ROE of approximately 10.89% on its generation and distribution services for the combined 2013 and 2014 test periods. Because this ROE was more than 70 basis points above Virginia Power’s authorized ROE of 10.0% , the Virginia Commission ordered that approximately $20 million in excess earnings be credited to customer bills based on usage in 2013 and 2014 over a six -month period beginning within 60 days of the 2015 Biennial Review Order. Based upon 2015 legislation keeping Virginia Power’s base rates unchanged until at least December 1, 2022, the Virginia Commission did not order certain existing rate adjustment clauses to be combined with Virginia Power’s base rates. The Virginia Commission did not determine whether Virginia Power had a revenue deficiency or sufficiency when projecting the annual revenues generated by base rates to the revenues required to recover costs of service and earn a fair return. In December 2015, a group of large industrial customers filed notices of appeal with the Supreme Court of Virginia from both the 2015 Biennial Review Order and the Virginia Commission’s order denying their petition for rehearing or reconsideration. This appeal is pending. Virginia Fuel Expenses In February 2015, Virginia Power submitted its annual fuel factor filing to the Virginia Commission. In August 2015, the Virginia Commission approved Virginia Power’s annual fuel factor filing to recover an estimated $1.6 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, 2015. Virginia Power’s new approved fuel rate, in effect on an interim basis since April 1, 2015, represents a fuel revenue decrease of $512 million when applied to projected kilowatt-hour sales for the period April 1, 2015 to June 30, 2016. Solar Facility Projects In January 2015, Virginia Power applied for a CPCN to construct and operate a 20 MW utility-scale solar facility near its existing Remington power station in Fauquier County, Virginia. The total estimated cost of the Remington solar facility was approximately $47 million , excluding financing costs . Virginia Power also applied for approval of Rider US-1 to recover the projected costs of the facility. In October 2015, the Virginia Commission denied approval of the CPCN and Rider US-1 based on the evidence in the record but stated that an application could be re-filed to address the concerns cited by the Virginia Commission. Virginia Power is assessing its options for re-filing. In October 2015, Virginia Power filed a CPCN with the Virginia Commission to construct three solar facilities. Woodland, Scott Solar and Whitehouse would increase Dominion’s renewable generation by a combined 56 MW and are estimated to cost approximately $130 million , excluding financing costs. Virginia Power also applied for approval of Rider US-2. This case is pending. The facilities are expected to commence commercial operations, subject to regulatory approvals, in the fourth quarter of 2016. Rate Adjustment Clauses Below is a discussion of significant riders associated with various Virginia Power projects: • The Virginia Commission previously approved Rider T1 concerning transmission rates. In May 2015, Virginia Power proposed a $668 million total revenue requirement for the rate year beginning September 1, 2015, which represents a $130 million increase over the previous year. Virginia Power also presented a mitigation proposal to defer $96 million of this revenue requirement to the rate year beginning September 1, 2016, which would reduce by 50% the one -year rate impact on residential customers. In August 2015, the Virginia Commission rejected the mitigation proposal and approved full recovery of the proposed revenue requirement. • The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2015, Virginia Power proposed a $250 million revenue requirement for the rate year beginning April 1, 2016, which represents a $5 million increase over the previous year. This case is pending. • The Virginia Commission previously approved Rider W in conjunction with Warren County. In June 2015, Virginia Power proposed a $118 million revenue requirement for the rate year beginning April 1, 2016, which represents a $17 million decrease versus the previous year. This case is pending. • The Virginia Commission previously approved Rider R in conjunction with Bear Garden. In June 2015, Virginia Power proposed a $74 million revenue requirement for the rate year beginning April 1, 2016, which represents a $10 million decrease versus the previous year. This case is pending. • The Virginia Commission previously approved Rider B in conjunction with the conversion of three power stations to biomass. In June 2015, Virginia Power proposed a $30 million revenue requirement for the rate year beginning April 1, 2016, which represents a $21 million increase over the previous year. This case is pending. • Virginia legislation which provides for the recovery of costs to move certain electric distribution facilities underground became effective in July 2014. In October 2014, Virginia Power filed for approval of Rider U, which proposed a revenue requirement of $28 million during the initial rate year beginning September 1, 2015. In May 2015, Virginia Power revised the revenue requirement to $24 million . In July 2015, the Virginia Commission denied approval of Rider U based on the evidence in the record, but found that an alternative plan addressing certain concerns, such as the lack of a cost-benefit analysis, could reasonably satisfy the regulatory requirements for approval. In December 2015, Virginia Power filed for approval of a more limited undergrounding program, along with a revised Rider U proposing a revenue requirement of $24 million for the initial rate year beginning September 1, 2016. This case is pending. • The Virginia Commission previously approved Riders C1A and C2A in connection with cost recovery for DSM programs. In August 2015, Virginia Power proposed a total revenue requirement of $50 million for the rate year beginning May 1, 2016. Virginia Power further proposed two new energy efficiency programs for Virginia Commission approval with a requested five -year cost cap of $51 million for those programs, and to extend an existing peak-shaving program for an additional five years under current funding. This case is pending. • The Virginia Commission previously approved Rider BW in conjunction with Brunswick County. In October 2015, Virginia Power proposed a $156 million total revenue requirement for the rate year beginning September 1, 2016, which represents a $45 million increase versus the previous year. This case is pending. • In July 2015, Virginia Power filed an application with the Virginia Commission for a CPCN to construct and operate Greensville County and related transmission interconnection facilities. Virginia Power also applied for approval of Rider GV to recover the costs of Greensville County, and proposed a total revenue requirement of $42 million for the rate year beginning April 1, 2016. This case is pending. Electric Transmission Projects 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. In April 2015, the Supreme Court of Virginia issued its opinion in the consolidated appeals of the Virginia Commission’s order granting a CPCN for the Skiffes Creek transmission line and related facilities. The Supreme Court of Virginia unanimously affirmed all but one of the alleged grounds for appeal. The court approved the proposed project including the proposed route for a 500 kV overhead transmission line from Surry to the Skiffes Creek switching station site. The court reversed and remanded the Virginia Commission’s determination in one set of appeals that the Skiffes Creek switching station was a transmission line for purposes of statutory exemption from local zoning ordinances. In May 2015, the Supreme Court of Virginia denied separate petitions filed by Virginia Power and the Virginia Commission to rehear its ruling regarding the Skiffes Creek switching station. Pending receipt of remaining required permits and approvals, Virginia Power expects to construct the project. In May 2015, Virginia Power filed an application with the Virginia Commission for a CPCN to construct and operate in Loudoun County, Virginia, a new approximately 230 kV Poland Road substation, and a new approximately four mile overhead 230 kV double circuit transmission line between the existing 230 kV Loudoun-Brambleton line and the Poland Road substation. The total estimated cost of the project is approximately $55 million . This case is pending. In November 2015, Virginia Power filed an application with the Virginia Commission for a CPCN to convert an existing transmission line to 230 kV in Prince William County, Virginia, and Loudoun County, Virginia, and to construct and operate a new approximately five mile overhead 230 kV double circuit transmission line between a tap point near the Gainesville substation and a new to-be-constructed Haymarket substation. The total estimated cost of the project is approximately $51 million . This case is pending. In November 2015, Virginia Power filed an application with the Virginia Commission for a CPCN to construct and operate in multiple Virginia counties an approximately 38 mile overhead 230 kV transmission line between the Remington and Gordonsville substations, along with associated facilities. The total estimated cost of the project is approximately $104 million . This case is pending. In February 2016, the Virginia Commission issued an order granting Virginia Power a CPCN to construct and operate the Remington CT-Warrenton 230 kV double circuit transmission line, the Vint Hill-Wheeler and Wheeler-Gainesville 230 kV lines and the 230 kV Vint Hill and Wheeler switching stations along Virginia Power’s proposed route. The total estimated cost of the project is approximately $105 million . 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. The COL is expected in 2017. Virginia Power has not yet committed to building a new nuclear unit at North Anna. The motions and petitions filed by BREDL prior to April 2015 have been dismissed, and under a previous ruling of the NRC, the contested portion of the COL proceeding remains terminated. The NRC is required to conduct a hearing in all COL proceedings, and if a new contention is not admitted, the mandatory NRC hearing will be uncontested. In April 2015, BREDL filed a new motion and petition seeking to object to the NRC’s reliance on the continued storage rule in licensing proceedings. The BREDL filings are substantially the same as those filed in other COL proceedings in which final environmental impact statements were issued prior to promulgation of the continued storage rule, like North Anna 3. In June 2015, the NRC denied the April 2015 motion and petition. In August 2015, BREDL filed a petition in the U.S. Court of Appeals for the D.C. Circuit seeking review of the NRC’s June 2015 decision. Along with the petition for judicial review, BREDL also filed a motion to hold this judicial review in abeyance pending the outcome of the ongoing judicial review of the NRC’s rule pertaining to the continued onsite storage of spent nuclear fuel in litigation pending before the same court. Similar petitions were filed seeking judicial review of the NRC’s decision as it applies to other COL and license renewal proceedings. Virginia Power has filed a motion with the court to intervene in the proceeding. This case is pending. 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 $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 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. 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. Following an appeal to the Supreme Court of North Carolina, the North Carolina Commission issued an opinion reaffirming its 10.2% ROE determination in July 2015. In August 2015, Virginia Power submitted its annual filing to the North Carolina Commission to adjust the fuel component of its electric rates. Virginia Power proposed an $11 million decrease to the fuel component of its electric rates for the rate year beginning January 1, 2016. This decrease includes the North Carolina Commission’s previous approval to defer recovering 50% of Virginia Power’s estimated $17 million jurisdictional deferred fuel balance to the 2016 fuel year, without interest. In December 2015, the North Carolina Commission approved Virginia Power’s proposed fuel charge adjustment. Ohio Regulation PIR Program In 2008, East Ohio began PIR, aimed at replacing approximately 25% of its pipeline system. In March 2015, East Ohio filed an application with the Ohio Commission requesting approval to extend the PIR program for an additional five years and to increase the annual capital investment, with corresponding increases in the annual rate-increase caps. In its application, East Ohio proposed that PIR investments for 2016 should fall under the existing authorization and that the new five -year period should include investment through December 31, 2021. East Ohio also proposed that the PIR investment should be increased by $20 million in 2017 and another $20 million in 2018, bringing the total annual investment to $200 million . Thereafter, East Ohio proposed capital investment increases of 3% per year for 2019 through 2021 to mitigate inflation and other cost pressures experienced to date, which will continue into the future. This case is pending. 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 application was approved by the Ohio Commission in April 2015. AMR Program In 2007, East Ohio began installing automated meter reading technology for its 1.2 million customers in Ohio. The AMR program approved by the Ohio Commission was completed in 2012. 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. 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. The filing reflects a projected revenue requirement of approximately $8 million . This application was approved by the Ohio Commission in April 2015. 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 amount is deferred and collected under the PIPP Rider in accordance with the rules of the Ohio Commission. In July 2015, 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 revised rider rate reflects the refund for the twelve-month period from July 2015 through June 2016 of an over-recovery of accumulated arrearages of approximately $57 million as of March 31, 2015, net of projected deferred program costs of approximately $35 million from April 2015 through June 2016. 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 2015, the Ohio Commission approved East Ohio’s application to decrease its UEX Rider, which reflects a refund of over-recovered accumulated bad debt expense of $14 million as of March 31, 2015, and recovery of prospective net bad debt expense projected to total approximately $20 million for the twelve-month period from April 2015 to March 2016. PSMP In October 2015, East Ohio requested approval from the Ohio Commission to defer the operation and maintenance costs associated with implementing a proposed PSMP. The costs are not expected to exceed $15 million per year. West Virginia Regulation In September 2015, Hope requested approval of PREP from the West Virginia Commission. In the application, Hope proposed a projected capital investment for 2016 of $24 million as part of a total five -year projected capital investment of $158 million . In January 2016, Hope and the West Virginia Commission reached a settlement allowing Hope to include costs related to capital investment for 2016 of $20 million in new PREP customer rates effective March 1, 2016. FERC - Gas During the second quarter of 2013, DCG executed binding precedent agreements for the approximately $35 million Edgemoor Project. FERC approved the Edgemoor Project in February 2015, construction commenced in March 2015 and the project was placed into service in December 2015. In April 2014, DCG executed a binding precedent agreement for the approximately $35 million Columbia to Eastover Project. In May 2015, DCG filed an application to request FERC authorization to construct and operate the project facilities, which are expected to be in service in the third quarter of 2016. In October 2015, Cove Point received authorization to construct the approximately $30 million St. Charles Transportation Project and the approximately $40 million Keys Energy Project. Construction on each project commenced in the fourth quarter of 2015. The St. Charles Transportation Project is anticipated to be placed into service in June 2016. The Keys Energy Project is anticipated to be placed into service in March 2017.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation [Abstract]
Asset Retirement Obligations	A SSET R ETIREMENT O BLIGATIONS 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 ash pond closures and 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 the retirement of Dominion's LNG facility, Dominion 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 or dispose of 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 2014 and 2015 were as follows: Amount (millions) Dominion AROs at December 31, 2013 $ 1,578 Obligations incurred during the period 40 Obligations settled during the period (82 ) Revisions in estimated cash flows (1) 102 Accretion 81 Other (5 ) AROs at December 31, 2014 (2) $ 1,714 Obligations incurred during the period (3) 315 Obligations settled during the period (106 ) Revisions in estimated cash flows (3) 88 Accretion 93 Other (1 ) AROs at December 31, 2015 (2) $ 2,103 Virginia Power AROs at December 31, 2013 $ 689 Obligations incurred during the period 28 Obligations settled during the period (1 ) Revisions in estimated cash flows (1) 108 Accretion 37 Other (6 ) AROs at December 31, 2014 $ 855 Obligations incurred during the period (3) 289 Obligations settled during the period (39 ) Revisions in estimated cash flows (3) 92 Accretion 50 AROs at December 31, 2015 $ 1,247 Dominion Gas AROs at December 31, 2013 $ 137 Obligations incurred during the period 2 Obligations settled during the period (8 ) Accretion 8 Other 8 AROs at December 31, 2014 (4) $ 147 Obligations incurred during the period 5 Obligations settled during the period (6 ) Revisions in estimated cash flows (5 ) Accretion 9 Other (1 ) AROs at December 31, 2015 (4) $ 149 (1) Relates primarily to a shift of the delayed planned date on which the DOE is expected to begin accepting spent nuclear fuel. (2) Includes $81 million and $216 million reported in other current liabilities at December 31, 2014, and 2015, respectively. (3) Primarily reflects future ash pond and landfill closure costs at certain utility generation facilities. See Note 22 for further information. (4) Includes $140 million and $137 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2014 and 2015, respectively. Dominion and Virginia Power have established trusts dedicated to funding the future decommissioning of their nuclear plants. At both December 31, 2015 and 2014, the aggregate fair value of Dominion's trusts, consisting primarily of equity and debt securities, totaled $4.2 billion . At both December 31, 2015 and 2014, the aggregate fair value of Virginia Power's trusts, consisting primarily of debt and equity securities, totaled $1.9 billion .

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities	V ARIABLE I NTEREST E NTITIES 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, which began commercial operations in June 2004, from Juniper, the lessor. 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. 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 and Dominion Gas Dominion Midstream and Dominion Gas own a 25.93% and 24.72% noncontrolling partnership interest in Iroquois, respectively. See Note 3 for further details regarding the nature of this entity. Dominion concluded that Iroquois is a VIE because a non-affiliated Iroquois equity holder has the ability during a limited period of time to transfer its ownership interests to another Iroquois equity holder or its affiliate. At December 31, 2015, Dominion concluded that neither Dominion Midstream nor Dominion Gas is the primary beneficiary of Iroquois as they do not have the power to direct the activities of Iroquois that most significantly impact its economic performance, as the power to direct is shared among multiple unrelated parties. If Iroquois determines capital contributions are required, Dominion Midstream and Dominion Gas each would be obligated to provide the portion of capital contributions based on its ownership percentage. Dominion Midstream's and Dominion Gas’ maximum exposure to loss is limited to their 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 had long-term power and capacity contracts with five non-utility generators, which contain certain variable pricing mechanisms in the form of partial fuel reimbursement that Virginia Power considers to be variable interests. Contracts with two of these non-utility generators expired during 2015 leaving a remaining aggregate summer generation capacity of approximately 418 MW. 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 remaining contracts expire at various dates ranging from 2017 to 2021. Virginia Power is not subject to any risk of loss from these potential VIEs other than its remaining purchase commitments which totaled $439 million as of December 31, 2015. Virginia Power paid $200 million , $223 million , and $217 million for electric capacity and $83 million , $138 million , and $98 million for electric energy to these entities for the years ended December 31, 2015, 2014 and 2013, respectively. Virginia Power and Dominion Gas Virginia Power and Dominion Gas purchased shared services from DRS, an affiliated VIE, of $318 million and $115 million , $335 million and $106 million , and $331 million and $115 million for the years ended December 31, 2015, 2014 and 2013, 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.

Short-Term Debt And Credit Agre

Short-Term Debt And Credit Agreements	12 Months Ended
	Dec. 31, 2015
Short-term Debt, Other Disclosures [Abstract]
Short-Term Debt and Credit Agreements	S HORT -T ERM D EBT AND C REDIT A GREEMENTS 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 January 2016, Dominion expanded its short-term funding resources through a $1.0 billion increase to one of its joint revolving credit facility limits. 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 Limit Outstanding Outstanding Facility (millions) At December 31, 2015 Joint revolving credit facility (1)(2) $ 4,000 $ 3,353 $ — $ 647 Joint revolving credit facility (1) 500 156 59 285 Total $ 4,500 $ 3,509 (3) $ 59 $ 932 At December 31, 2014 Joint revolving credit facility (1) $ 4,000 $ 2,664 $ — $ 1,336 Joint revolving credit facility (1) 500 111 48 341 Total $ 4,500 $ 2,775 (3) $ 48 $ 1,677 (1) These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to a combined $2.0 billion of letters of credit. (2) In January 2016, this facility limit was increased from $4.0 billion to $5.0 billion . (3) The weighted-average interest rates of the outstanding commercial paper supported by Dominion’s credit facilities were 0.62% and 0.38% at December 31, 2015 and 2014, respectively. Virginia Power Virginia Power’s short-term financing is supported through its access as co-borrower to the two joint revolving credit facilities. These credit facilities can be 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 under its joint credit facilities with Dominion and Dominion Gas were as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) At December 31, 2015 Joint revolving credit facility (1)(2) $ 4,000 $ 1,500 $ — Joint revolving credit facility (1) 500 156 — Total $ 4,500 $ 1,656 (3) $ — At December 31, 2014 Joint revolving credit facility (1) $ 4,000 $ 1,250 $ — Joint revolving credit facility (1) 500 111 — Total $ 4,500 $ 1,361 (3) $ — (1) The full amount of the facilities is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion and Dominion Gas. Sub-limits for Virginia Power are set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2015, the sub-limit for Virginia Power was an aggregate $1.75 billion . If Virginia Power has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion. These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $2.0 billion (or the sub-limit, whichever is less) of letters of credit. (2) In January 2016, this facility limit was increased from $4.0 billion to $5.0 billion . (3) The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.60% and 0.36% at December 31, 2015 and 2014, respectively. In addition to the credit facility commitments mentioned above, Virginia Power also has a $120 million credit facility with a maturity date of April 2019. As of December 31, 2015, this facility supports $119 million of certain variable rate tax-exempt financings of Virginia Power. Dominion Gas Dominion Gas’ short-term financing is supported by its access as co-borrower to the two joint revolving credit facilities. 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' share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Virginia Power were as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) At December 31, 2015 Joint revolving credit facility (1) $ 1,000 $ 391 $ — Joint revolving credit facility (1) 500 — — Total $ 1,500 $ 391 (2) $ — At December 31, 2014 Joint revolving credit facility (1) $ 1,000 $ — $ — Joint revolving credit facility (1) 500 — — Total $ 1,500 $ — $ — (1) A maximum of a combined $1.5 billion of the facilities is available to Dominion Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion and Virginia Power. Sub-limits for Dominion Gas are set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2015, the sub-limit for Dominion Gas was an aggregate $500 million . In January 2016, the aggregate sub-limit for Dominion Gas was increased to $1.0 billion . If Dominion Gas has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion. These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (or the sub-limit, whichever is less) of letters of credit. (2) The weighted-average interest rate of the outstanding commercial paper supported by these credit facilities was 0.63% at December 31, 2015.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2015
Long-term Debt, Unclassified [Abstract]
Long-Term Debt	L ONG -T ERM D EBT At December 31, 2015 Weighted- average Coupon (1) 2015 2014 (millions, except percentages) Dominion Gas Holdings, LLC: Unsecured Senior Notes: 1.05% to 2.8%, due 2016 to 2020 2.26 % $ 1,550 $ 850 3.55% to 4.8%, due 2023 to 2044 4.15 % 1,750 1,750 Dominion Gas Holdings, LLC total principal $ 3,300 $ 2,600 Securities due within one year 1.05 % (400 ) Unamortized discount (8 ) (6 ) Dominion Gas Holdings, LLC total long-term debt $ 2,892 $ 2,594 Virginia Electric and Power Company: Unsecured Senior Notes: 1.2% to 8.625%, due 2015 to 2019 5.03 % $ 2,261 $ 2,471 2.75% to 8.875%, due 2022 to 2045 4.91 % 6,292 5,592 Tax-Exempt Financings (2) : Variable rates, due 2016 to 2041 0.79 % 194 606 0.70% to 5.6%, due 2023 to 2041 2.19 % 678 266 Virginia Electric and Power Company total principal $ 9,425 $ 8,935 Securities due within one year 5.24 % (476 ) (211 ) Unamortized discount and premium, net — 2 Virginia Electric and Power Company total long-term debt $ 8,949 $ 8,726 Dominion Resources, Inc.: Unsecured Senior Notes: Variable rates, due 2015 and 2016 1.11 % $ 600 $ 400 1.25% to 6.4%, due 2015 to 2019 3.05 % 3,400 3,150 2.75% to 7.0%, due 2021 to 2044 (3) 4.80 % 5,099 4,449 Tax-Exempt Financing, variable rate, due 2041 1.16 % 75 75 Unsecured Junior Subordinated Notes Payable to Affiliated Trust, 8.4%, due 2031 8.40 % 10 10 Enhanced Junior Subordinated Notes: 5.75% and 7.5%, due 2054 and 2066 6.27 % 971 985 Variable rate, due 2066 2.90 % 377 380 Remarketable Subordinated Notes, 1.07% to 1.50%, due 2019 to 2021 1.30 % 2,100 2,100 Unsecured Debentures and Senior Notes (4) : 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) 3,300 2,600 Virginia Electric and Power Company total principal (from above) 9,425 8,935 Dominion Resources, Inc. total principal $ 25,473 $ 23,200 Fair value hedge valuation (5) 7 19 Securities due within one year (6) 2.38 % (1,826 ) (1,375 ) Unamortized discount and premium, net (38 ) (39 ) Dominion Resources, Inc. total long-term debt $ 23,616 $ 21,805 (1) Represents weighted-average coupon rates for debt outstanding as of December 31, 2015. (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 were 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 Dominion’s Consolidated Balance Sheets. The option to redeem the notes expired in June 2015. At December 31, 2015, the notes are included in long-term debt in Dominion’s 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 for fair value hedge valuation in 2014. Excludes $100 million of variable rate short-term notes scheduled to mature in May 2016 that were purchased and cancelled using the proceeds from the February 2016 issuance of senior notes that mature in 2018. 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, 2015, were as follows: 2016 2017 2018 2019 2020 Thereafter Total (millions, except percentages) Dominion Gas $ 400 $ — $ — $ 450 $ 700 $ 1,750 $ 3,300 Weighted-average Coupon 1.05 % 2.50 % 2.80 % 4.15 % Virginia Power $ 476 $ 679 $ 850 $ 350 $ — $ 7,070 $ 9,425 Weighted-average Coupon 5.24 % 5.44 % 4.17 % 5.00 % — % 4.59 % Dominion Unsecured Senior Notes (1) $ 1,907 $ 1,354 $ 1,850 $ 2,000 $ 700 $ 13,230 $ 21,041 Tax-Exempt Financings 19 75 — — — 880 974 Unsecured Junior Subordinated Notes Payable to Affiliated Trusts — — — — — 10 10 Enhanced Junior Subordinated Notes — — — — — 1,348 1,348 Remarketable Subordinated Notes — — — 550 1,000 550 2,100 Total $ 1,926 $ 1,429 $ 1,850 $ 2,550 $ 1,700 $ 16,018 $ 25,473 Weighted-average Coupon 2.31 % 3.28 % 4.16 % 3.09 % 2.04 % 4.54 % (1) In February 2016, Dominion purchased and cancelled $100 million of variable rate short-term notes that would have otherwise matured in May 2016 using the proceeds from the February 2016 issuance of senior notes that mature in 2018. As a result, at December 31, 2015, $100 million of the notes were included in long-term debt 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, 2015, there were no events of default under these covenants. In January 2016, Virginia Power issued $750 million of 3.15% senior notes that mature in 2026. In February 2016, Dominion issued $500 million of 2.125% senior notes in a private placement. The notes mature in 2018. Senior Note Redemptions As part of Dominion's Liability Management Exercise, in December 2014, Dominion redeemed five outstanding series of senior notes with an aggregate outstanding principal of $1.9 billion . The aggregate redemption price paid in December 2014 was $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 2014. However, 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, 2015, 2014 and 2013. 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. 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. In 2015, Dominion purchased and canceled $14 million and $3 million of the June 2006 hybrids and the September 2006 hybrids, respectively. In the first quarter of 2016, Dominion purchased and cancelled $37 million and $2 million of the June 2006 hybrids and the September 2006 hybrids, respectively. 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 $1.0 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. Pursuant to the terms of the 2013 Equity Units and 2014 Equity Units, Dominion expects to remarket the 2013 Series A, 2013 Series B and 2014 Series A RSNs during the first and second quarters of 2016, and the second quarter of 2017, respectively. Following a successful remarketing, the interest rate on the RSNs will be reset, interest will be payable on a semiannual basis and Dominion will cease to have the ability to redeem the RSNs at its option or defer interest payments. Proceeds of each remarketing will belong to the investors in the related equity units and will be held and applied on their behalf at the settlement date of the related stock purchase contracts to pay the purchase price to Dominion for issuance of its common stock. Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, Dominion will issue between 8.5 million and 10.0 million shares of its common stock in both April 2016 and July 2016 and between 11.5 million and 14.4 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) 6/7/2013 11 $ 533.5 $ 550.0 1.070 % 5.055 % $ 76.7 4/1/2016 4/1/2021 6/7/2013 11 $ 553.5 $ 550.0 1.180 % 4.820 % $ 79.3 7/1/2016 7/1/2019 7/1/2014 20 $ 982.0 $ 1,000.0 1.500 % 4.875 % $ 142.8 7/1/2017 7/1/2020 (1) Payments of $101 million and $66 million were made in 2015 and 2014, respectively. The stock purchase contract liability was $115 million and $216 million at December 31, 2015 and 2014, respectively.

Preferred Stock

Preferred Stock	12 Months Ended
	Dec. 31, 2015
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Preferred Stock	P REFERRED S TOCK Dominion is authorized to issue up to 20 million shares of preferred stock; however, none were issued and outstanding at December 31, 2015 or 2014. Virginia Power is authorized to issue up to 10 million shares of preferred stock, $100 liquidation preference. During 2014, Virginia Power redeemed 2.59 million shares, which represented all outstanding series of its preferred stock, some of which were redeemed as a part of Dominion's Liability Management Exercise in September 2014. Upon redemption, each series was no longer outstanding for any purpose and dividends ceased to accumulate. Virginia Power had no preferred stock issued and outstanding at December 31, 2015 or 2014.

Equity

Equity	12 Months Ended
	Dec. 31, 2015
Stockholders' Equity Note [Abstract]
Equity	E QUITY 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 2015, Dominion received cash proceeds, net of fees and commissions, of $783 million from the issuance of approximately 11 million shares of common stock through various programs resulting in approximately 596 million of shares of common stock outstanding at December 31, 2015. These proceeds include cash of $284 million received from the issuance of 4.1 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. During the first and second quarters of 2015, Dominion provided sales instructions to the sales agents and issued 4.0 million shares through at-the-market issuances and received cash proceeds of $297 million , net of fees and commissions paid of $3 million . Following these issuances, Dominion has the ability to issue up to approximately $200 million of stock under the 2014 sales agency agreements. However, Dominion completed its 2015 planned market issuances of equity in May 2015 with the issuance of 2.8 million shares and receipt of proceeds of $202 million through a registered underwritten public offering. VIRGINIA POWER In 2015, 2014 and 2013, 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, 2015, Dominion had approximately 50 million shares reserved and available for issuance for Dominion Direct ® , employee stock awards, employee savings plans, director stock compensation plans 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 2015 or 2014 and does not plan to repurchase shares during 2016, except for shares tendered by employees to satisfy tax withholding obligations on vested restricted stock, which do not count against its stock repurchase authorization. Purchase of Dominion Midstream Units In September 2015, Dominion initiated a program to purchase from the market up to $50 million of common units representing limited partner interests in Dominion Midstream. The common units may be acquired by Dominion over the 12 month period following commencement of the program at the discretion of management. Through December 31, 2015, Dominion purchased approximately 887,000 common units for $25 million . In the first quarter of 2016, Dominion purchased approximately 377,000 additional common units for approximately $10 million . At February 23, 2016, Dominion still has the ability to purchase up to $15 million of common units under the program. Accumulated Other Comprehensive Income (Loss) Presented in the table below is a summary of AOCI by component: At December 31, 2015 2014 (millions) Dominion Net deferred losses on derivatives-hedging activities, net of tax of $110 and $116 $ (176 ) $ (178 ) Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(281) and $(333) 504 548 Net unrecognized pension and other postretirement benefit costs, net of tax of $525 and $530 (797 ) (782 ) Other comprehensive loss from equity method investees, net of tax of $4 and $3 (5 ) (4 ) Total AOCI $ (474 ) $ (416 ) Virginia Power Net deferred losses on derivatives-hedging activities, net of tax of $4 and $4 $ (7 ) $ (7 ) Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(30) and $(35) 47 57 Total AOCI $ 40 $ 50 Dominion Gas Net deferred losses on derivatives-hedging activities, net of tax of $10 and $11 $ (17 ) $ (20 ) Net unrecognized pension costs, net of tax of $56 and $46 (82 ) (66 ) Total AOCI $ (99 ) $ (86 ) 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, 2015 Beginning balance $ (178 ) $ 548 $ (782 ) $ (4 ) $ (416 ) Other comprehensive income before reclassifications: gains (losses) 110 6 (66 ) (1 ) 49 Amounts reclassified from AOCI: (gains) losses (1) (108 ) (50 ) 51 — (107 ) Net current period other comprehensive income (loss) 2 (44 ) (15 ) (1 ) (58 ) Ending balance $ (176 ) $ 504 $ (797 ) $ (5 ) $ (474 ) 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 AOCI: (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 ) (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, 2015 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (203 ) Operating revenue 15 Purchased gas 1 Electric fuel and other energy-related purchases Interest rate contracts 11 Interest and related charges Total (176 ) Tax 68 Income tax expense Total, net of tax $ (108 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (110 ) Other income Impairment 31 Other income Total (79 ) Tax 29 Income tax expense Total, net of tax $ (50 ) Unrecognized pension and other postretirement benefit costs: Prior-service costs (credits) $ (12 ) Other operations and maintenance Actuarial losses 98 Other operations and maintenance Total 86 Tax (35 ) Income tax expense Total, net of tax $ 51 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 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, 2015 Beginning balance $ (7 ) $ 57 $ 50 Other comprehensive income before reclassifications: losses (1 ) (4 ) (5 ) Amounts reclassified from AOCI: (gains) losses (1) 1 (6 ) (5 ) Net current period other comprehensive income (loss) — (10 ) (10 ) Ending balance $ (7 ) $ 47 $ 40 Year Ended December 31, 2014 Beginning balance $ — $ 48 $ 48 Other comprehensive income before reclassifications: gains (losses) (4 ) 15 11 Amounts reclassified from AOCI: gains (1) (3 ) (6 ) (9 ) Net current period other comprehensive income (loss) (7 ) 9 2 Ending balance $ (7 ) $ 57 $ 50 (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, 2015 (Gains) losses on cash flow hedges: Commodity contracts $ 1 Electric fuel and other energy-related purchases Total 1 Tax — Income tax expense Total, net of tax $ 1 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (14 ) Other income Impairment 4 Other income Total (10 ) Tax 4 Income tax expense Total, net of tax $ (6 ) Year Ended December 31, 2014 (Gains) losses on cash flow hedges: Commodity contracts $ (5 ) Electric fuel and other energy-related purchases 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 ) 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 costs Total (millions) Year Ended December 31, 2015 Beginning balance $ (20 ) $ (66 ) $ (86 ) Other comprehensive income before reclassifications: gains (losses) 6 (20 ) (14 ) Amounts reclassified from AOCI: (gains) losses (1) (3 ) 4 1 Net current period other comprehensive income (loss) 3 (16 ) (13 ) Ending balance $ (17 ) $ (82 ) $ (99 ) Year Ended December 31, 2014 Beginning balance $ 3 $ (61 ) $ (58 ) Other comprehensive income before reclassifications: losses (31 ) (10 ) (41 ) Amounts reclassified from AOCI losses (1) 8 5 13 Net current period other comprehensive loss (23 ) (5 ) (28 ) Ending balance $ (20 ) $ (66 ) $ (86 ) (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, 2015 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (6 ) Operating revenue Total (6 ) Tax 3 Income tax expense Total, net of tax $ (3 ) Unrecognized pension costs: Actuarial losses $ 7 Other operations and maintenance Total 7 Tax (3 ) Income tax expense Total, net of tax $ 4 Year Ended December 31, 2014 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (2 ) Operating revenue 14 Purchased gas Interest rate contracts 1 Interest and related charges Total 13 Tax (5 ) Income tax expense Total, net of tax $ 8 Unrecognized pension 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 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, 2015, approximately 25 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, 2015, 2014 and 2013 include $39 million , $39 million , and $31 million , respectively, of compensation costs and $14 million , $14 million , and $11 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. Dominion realized $3 million of excess tax benefits from the vesting of restricted stock awards and exercise of stock options during the year ended December 31, 2015, and less than $1 million during the years ended December 31, 2014 and 2013. 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, 2015, 2014 and 2013: Shares Weighted - average Grant Date Fair Value (thousands) Nonvested at December 31, 2012 1,085 $ 44.46 Granted 312 54.70 Vested (356 ) 39.00 Cancelled and forfeited (34 ) 51.11 Nonvested at December 31, 2013 1,007 $ 49.35 Granted 354 67.98 Vested (278 ) 44.50 Cancelled and forfeited (18 ) 53.61 Nonvested at December 31, 2014 1,065 $ 56.74 Granted 302 73.26 Vested (510 ) 50.71 Cancelled and forfeited (2 ) 62.62 Nonvested at December 31, 2015 855 $ 66.16 As of December 31, 2015, unrecognized compensation cost related to nonvested restricted stock awards totaled $27 million and is expected to be recognized over a weighted-average period of 2.0 years. The fair value of restricted stock awards that vested was $37 million , $19 million , and $20 million in 2015, 2014 and 2013, 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 2014 and February 2015. 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, 2015, 2014 and 2013: Targeted Number of Shares Weighted - average Grant Date Fair Value (thousands) Nonvested at December 31, 2012 4 $ 45.60 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 Granted 14 72.72 Vested (7 ) 56.22 Nonvested at December 31, 2015 24 $ 72.27 At December 31, 2015, the targeted number of shares expected to be issued under the February 2014 and February 2015 awards was approximately 24 thousand . In January 2016, the CGN Committee determined the actual performance against metrics established for the February 2014 awards with a performance period that ended December 31, 2015. Based on that determination, the total number of shares to be issued under the February 2014 goal-based stock awards was approximately 10 thousand . As of December 31, 2015, 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 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 amount of the award under the grant was $20 million and the remaining portion of the grant was paid in February 2015. 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. The total expected award under the grant is $10 million and the grant is expected to be paid by March 15, 2016. At December 31, 2015, a liability of $10 million had been accrued for this award. In February 2015, a cash-based performance grant was made to officers. Payout of the performance grant is expected to occur by March 15, 2017 based on the achievement of two performance metrics during 2015 and 2016: 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, 2015, the targeted amount of the grant was $14 million and a liability of $7 million had been accrued for this award.

Dividend Restrictions

Dividend Restrictions	12 Months Ended
	Dec. 31, 2015
Disclosure of Restrictions on Dividends, Loans and Advances Disclosure [Abstract]
Dividend Restrictions	D IVIDEND R ESTRICTIONS 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, 2015, 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, 2015, 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, 2015. 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, 2015
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Employee Benefit Plans	E MPLOYEE B ENEFIT P LANS 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. Dominion's pension and other postretirement plan assets experienced aggregate actual losses of $72 million in 2015 and aggregate actual returns of $706 million in 2014, versus expected returns of $648 million and $610 million , respectively. Dominion Gas' pension and other postretirement plan assets for employees represented by collective bargaining units experienced aggregate actual losses of $13 million in 2015 and aggregate actual returns of $157 million in 2014, versus expected returns of $150 million and $138 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 and Dominion Gas received a federal subsidy of $4 million and $1 million , respectively, for 2014. 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 begins to receive an increased level of Medicare Part D subsidies in the form of reduced costs rather than a direct reimbursement. 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 increased net periodic benefit cost for Dominion and Dominion Gas (for employees represented by collective bargaining units) by $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 $354 million and a reduction in the accumulated postretirement benefit obligation of $78 million . For Dominion Gas employees represented by collective bargaining units, the remeasurement resulted in a reduction in the pension benefit obligation of $28 million and a reduction in the accumulated postretirement benefit obligation of $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 $36 million , excluding the impacts of curtailments, and for Dominion Gas employees represented by collective bargaining units by $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 $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 $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 $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 Year Ended December 31, 2015 2014 2015 2014 (millions, except percentages) DOMINION Changes in benefit obligation: Benefit obligation at beginning of year $ 6,667 $ 5,625 $ 1,571 $ 1,360 Service cost 126 114 40 32 Interest cost 287 290 67 67 Benefits paid (246 ) (236 ) (79 ) (78 ) Actuarial (gains) losses during the year (443 ) 887 (138 ) 177 Plan amendments (1) — — (31 ) 9 Settlements and curtailments (2) — (13 ) — — Medicare Part D reimbursement — — — 4 Benefit obligation at end of year $ 6,391 $ 6,667 $ 1,430 $ 1,571 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 6,480 $ 6,113 $ 1,402 $ 1,315 Actual return (loss) on plan assets (71 ) 601 (1 ) 105 Employer contributions 3 15 12 12 Benefits paid (246 ) (236 ) (31 ) (30 ) Settlements (2) — (13 ) — — Fair value of plan assets at end of year $ 6,166 $ 6,480 $ 1,382 $ 1,402 Funded status at end of year $ (225 ) $ (187 ) $ (48 ) $ (169 ) Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 931 $ 946 $ 12 $ 10 Other current liabilities (14 ) (13 ) (3 ) (3 ) Noncurrent pension and other postretirement benefit liabilities (1,142 ) (1,120 ) (57 ) (176 ) Net amount recognized $ (225 ) $ (187 ) $ (48 ) $ (169 ) Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.96% - 4.99% 4.40 % 4.93% - 4.94% 4.40 % Weighted average rate of increase for compensation 4.22 % 4.22 % 4.22 % 4.22 % Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.50 % 8.50 % DOMINION GAS Changes in benefit obligation: Benefit obligation at beginning of year $ 638 $ 563 $ 320 $ 269 Service cost 15 12 7 6 Interest cost 27 28 14 13 Benefits paid (29 ) (29 ) (18 ) (16 ) Actuarial (gains) losses during the year (43 ) 64 (31 ) 38 Plan amendments — — — 9 Medicare Part D reimbursement — — — 1 Benefit obligation at end of year $ 608 $ 638 $ 292 $ 320 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 1,510 $ 1,403 $ 288 $ 273 Actual return (loss) on plan assets (14 ) 136 1 21 Employer contributions — — 12 10 Benefits paid (29 ) (29 ) (18 ) (16 ) Fair value of plan assets at end of year $ 1,467 $ 1,510 $ 283 $ 288 Funded status at end of year $ 859 $ 872 $ (9 ) $ (32 ) Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 859 $ 872 $ — $ — Noncurrent pension and other postretirement benefit liabilities (3) — — (9 ) (32 ) Net amount recognized $ 859 $ 872 $ (9 ) $ (32 ) Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.99 % 4.40 % 4.93 % 4.40 % 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 % 8.75 % 8.50 % 8.50 % (1) 2015 amount relates primarily to a plan amendment that changed retiree medical benefits for certain nonunion employees after Medicare eligibility. (2) Relates primarily to a settlement charge for certain executives. (3) 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 $5.8 billion and $6.0 billion at December 31, 2015 and 2014, respectively. The ABO for the defined benefit pension plans covering Dominion Gas employees represented by collective bargaining units was $578 million and $604 million at December 31, 2015 and 2014, 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 2015, Dominion and Dominion Gas made no contributions to the qualified defined benefit pension plans and no contributions are currently expected in 2016. 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 2015 and 2014, and Dominion expects to contribute approximately $12 million to the Dominion VEBAs in 2016, 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 2016. 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, 2015 2014 2015 2014 (millions) DOMINION Benefit obligation $ 5,728 $ 5,970 $ 359 $ 1,564 Fair value of plan assets 4,571 4,838 299 1,385 DOMINION GAS Benefit obligation $ — $ — $ 292 $ 320 Fair value of plan assets — — 283 288 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, 2015 2014 (millions) Accumulated benefit obligation $ 5,198 $ 5,370 Fair value of plan assets 4,571 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 2016 $ 288 $ 92 2017 303 96 2018 324 99 2019 337 100 2020 359 102 2021-2025 2,023 512 DOMINION GAS 2016 $ 35 $ 18 2017 37 19 2018 39 21 2019 40 21 2020 41 21 2021-2025 208 107 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, 35% fixed income, 3% real estate and 16% 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: At December 31, 2015 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) DOMINION Cash equivalents $ 16 $ — $ — $ 16 $ 13 $ 25 $ — $ 38 U.S. equity: Large Cap 1,178 — — 1,178 1,313 — — 1,313 Other 475 — — 475 530 — — 530 Non-U.S. equity: Large Cap 286 — — 286 234 — — 234 Other 493 — — 493 403 — — 403 Common/collective trust funds (1) — 330 — 330 — 360 — 360 Fixed income: Corporate debt instruments 40 672 — 712 45 666 — 711 U.S. Treasury securities and agency debentures 60 298 — 358 74 342 — 416 State and municipal 20 54 — 74 10 60 — 70 Other securities 9 61 — 70 6 80 — 86 Real estate-REITs 90 — — 90 40 — — 40 Total recorded at fair value $ 2,667 $ 1,415 $ — $ 4,082 $ 2,668 $ 1,533 $ — $ 4,201 Assets recorded at NAV (2) : Common/collective trust funds (1) 1,200 1,235 Real estate-Partnerships 153 209 Other alternative investments: Private equity 465 518 Debt 170 144 Hedge funds 86 162 Total recorded at NAV $ 2,074 $ 2,268 Total (3) $ 6,156 $ 6,469 DOMINION GAS Cash equivalents $ 4 $ — $ — $ 4 $ 3 $ 6 $ — $ 9 U.S. equity: Large Cap 280 — — 280 306 — — 306 Other 113 — — 113 124 — — 124 Non-U.S. equity: Large Cap 68 — — 68 54 — — 54 Other 117 — — 117 94 — — 94 Common/collective trust funds (4) — 78 — 78 — 84 — 84 Fixed income: Corporate debt instruments 9 160 — 169 11 155 — 166 U.S. Treasury securities and agency debentures 14 71 — 85 17 80 — 97 State and municipal 5 13 — 18 2 14 — 16 Other securities 2 14 — 16 1 19 — 20 Real estate-REITs: 22 — — 22 9 — — 9 Total recorded at fair value $ 634 $ 336 $ — $ 970 $ 621 $ 358 $ — $ 979 Assets recorded at NAV (2) : Common/collective trust funds (4) 286 288 Real estate-Partnerships 36 48 Other alternative investments: Private equity 111 121 Debt 40 34 Hedge funds 21 38 Total recorded at NAV $ 494 $ 529 Total (5) $ 1,464 $ 1,508 (1) Common/collective trust funds include $330 million and $360 million of John Hancock insurance contracts held at December 31, 2015 and 2014, 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) These investments that are measured at fair value using the NAV per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Consolidated Balance Sheets. (3) Includes net assets related to pending sales of securities of $112 million , net accrued income of $16 million , and excludes net assets related to pending purchases of securities of $118 million at December 31, 2015. 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. (4) Common/collective trust funds include $78 million and $84 million of John Hancock insurance contracts held at December 31, 2015 and 2014, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund. (5) Includes net assets related to pending sales of securities of $27 million , net accrued income of $4 million , and excludes net assets related to pending purchases of securities of $28 million at December 31, 2015. 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: At December 31, 2015 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) DOMINION Cash equivalents $ 1 $ 1 $ — $ 2 $ 1 $ 7 $ — $ 8 U.S. equity: Large Cap 468 — — 468 514 — — 514 Other 26 — — 26 28 — — 28 Non-U.S. equity: Large Cap 107 — — 107 102 — — 102 Other 27 — — 27 21 — — 21 Common/collective trust funds (1) — 18 — 18 — 19 — 19 Fixed income: Corporate debt instruments 2 37 — 39 3 35 — 38 U.S. Treasury securities and agency debentures 3 17 — 20 4 18 — 22 State and municipal 1 3 — 4 1 3 — 4 Other securities 1 3 — 4 — 4 — 4 Real estate-REITs 37 — — 37 2 — — 2 Total recorded at fair value $ 673 $ 79 $ — $ 752 $ 676 $ 86 $ — $ 762 Assets recorded at NAV (2) : Common/collective trust funds (1) 543 536 Real estate-Partnerships 14 19 Other alternative investments: Private equity 54 58 Debt 14 18 Hedge funds 5 9 Total recorded at NAV $ 630 $ 640 Total $ 1,382 $ 1,402 DOMINION GAS Cash equivalents $ — $ — $ — $ — $ — $ 2 $ — $ 2 U.S. equity-Large Cap 102 — — 102 113 — — 113 Non-U.S. equity-Large Cap 24 — — 24 26 — — 26 Real estate-REITs 11 — — 11 — — — — Total recorded at fair value $ 137 $ — $ — $ 137 $ 139 $ 2 $ — $ 141 Assets recorded at NAV (2) : Common/collective trust funds (3) 132 129 Real estate-Partnerships 2 2 Other alternative investments: Private equity 11 12 Debt 1 4 Total recorded at NAV $ 146 $ 147 Total $ 283 $ 288 (1) Common/collective trust funds include $18 million and $19 million of John Hancock insurance contracts held at December 31, 2015 and 2014, 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) These investments that are measured at fair value using the NAV per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Consolidated Balance Sheets. (3) See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund. 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. • SSgA S&P 500 Flagship Non-Lending Fund-The Fund seeks an investment return that approximates as closely as practicable, before expenses, the performance of the S&P 500 Index over the long term. The S&P 500 is comprised of approximately 500 large-cap U.S. equities and captures approximately 80% coverage of available market capitalization. SSgA will typically attempt to invest in the equity securities comprising the S&P 500 Index, in approximately the same proportions as they are represented in the Index. • CF Goldman Sachs GSTCO Long Duration Fund-The Fund seeks to generate total return and prudent investment management through investments in fixed income securities. The Fund is actively managed and benchmarked versus the Barclays U.S. Long Government /Credit Index. At least 75% of the Fund’s total assets will be rated investment grade or better by a NRSRO at the time of purchase. The Fund may invest up to 25% of its total assets at the time of purchase in non-investment grade securities. The Fund may invest in non-dollar denominated securities that are fully hedged, unhedged or partially hedged. • 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. • 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 f

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	C OMMITMENTS AND C ONTINGENCIES 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 for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. 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. A IR CAA 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. MATS 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 was required by April 16, 2015, with certain limited exceptions. However, in June 2014, the Virginia Department of Environmental Quality 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. These coal units will need to continue operating until at least April 2017 due to delays in transmission upgrades needed to maintain electric reliability, which based on assumptions about the timing for required agency actions and construction schedules are expected to be completed by no earlier than the second quarter of 2017. Therefore, in October 2015 Virginia Power submitted a request to the EPA for an additional one year compliance extension under an EPA Administrative Order. In June 2015, the U.S. Supreme Court issued a decision holding that the EPA failed to take cost into account when the agency first decided to regulate the emissions from coal- and oil-fired plants, and remanded the MATS rule back to the D.C. Circuit Court. However, the Supreme Court did not vacate or stay the effective date and implementation of the MATS rule. On November 20, 2015, in response to the Supreme Court decision, the EPA proposed a supplemental finding that consideration of cost does not alter the agency’s previous conclusion that it is appropriate and necessary to regulate coal- and oil-fired electric utility steam generating units under Section 112 of the CAA. On December 15, 2015, the D.C. Court of Appeals issued an order remanding the MATS rulemaking proceeding back to the EPA without setting aside judgment, noting that EPA had represented it was on track to issue by April 15, 2016, a final finding regarding its consideration of cost. These actions do not change Virginia Power’s plans to close coal units at Yorktown or the need to complete necessary electricity transmission upgrades by 2017. Since the MATS rule remains in effect and Dominion is complying with the requirements of the rule, Dominion does not expect any adverse impacts to its operations at this time. CAIR The EPA established CAIR with the intent to require significant reductions in SO 2 and NO X emissions from electric generating facilities. In July 2008, the U.S. Court of Appeals for the D.C. Circuit issued a ruling vacating CAIR. In December 2008, the Court denied rehearing, but also issued a decision to remand CAIR to the EPA. In July 2011, the EPA issued a replacement rule for CAIR, called CSAPR, that required 28 states to reduce power plant emissions that cross state lines. CSAPR established new SO 2 and NO X emissions cap and trade programs that were completely independent of the current ARP. Specifically, CSAPR required reductions in SO 2 and NO X emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NO X emissions caps, NO X emissions caps during the ozone season (May 1 through September 30) and annual SO 2 emission caps with differing requirements for two groups of affected states. CSAPR 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 replaced 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. Ozone Standards In October 2015, the EPA issued a final rule tightening the ozone standard from 75 -ppb to 70 -ppb. The EPA is expected to complete attainment designations for a new standard by December 2017 and states will have until 2020 or 2021 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. Hazardous Air Pollutants Standards In August 2010, the EPA issued revised National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines, which 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 has spent $2 million to install emissions controls on several compressor engines. Further capital spending is not expected to be material. NSPS 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 VOC emissions for natural gas production wells, tanks, pneumatic controllers, and compressors in the upstream sector. In September 2015, the EPA issued a proposed NSPS to regulate methane and VOC emissions from transmission and storage, gathering and boosting, production and processing facilities. All projects which commence construction after September 2015 will be required to comply with this regulation. Dominion is evaluating the proposed regulation and cannot currently estimate the potential impacts on results of operations, financial condition and/or cash flows related to this matter. Methane Emissions In January 2015, as part of its Climate Action Plan, the EPA announced plans to reduce methane emissions from the oil and gas sector including natural gas processing and transmission sources. In July 2015, the EPA announced the next generation of its voluntary Natural Gas STAR program, the Natural Gas STAR Methane Challenge Program. The proposed program covers the entire natural gas sector from production to distribution, with more emphasis on transparency and increased reporting for both annual emissions and reductions achieved through implementation measures. Dominion is evaluating the proposed program and cannot currently estimate the potential impacts on results of operations, financial condition and/or cash flows related to this matter. C LIMATE C HANGE L EGISLATION AND R EGULATION 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. In July 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 August 2015, the EPA published a final rule rescinding the requirement for all new and modified major sources to obtain permits based solely on their GHG emissions. 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 CO 2 emissions for biomass projects. This rule temporarily deferred for a period of up to three years the consideration of CO 2 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 CO 2 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. W ATER 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 2015, the EPA released a final rule to revise the Effluent Limitations Guidelines for the Steam Electric Power Generating Category. The final rule establishes updated standards for wastewater discharges that apply primarily at coal and oil steam generating stations. Affected facilities are required to convert from wet to dry or closed cycle coal ash management, improve existing wastewater treatment systems and/or install new wastewater treatment technologies in order to meet the new discharge limits. Virginia Power has eight facilities that may be subject to additional wastewater treatment requirements associated with the final rule. The expenditures to comply with these new requirements are expected to be material. S OLID AND H AZARDOUS W ASTE 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. See below for discussion on ash pond and landfill closure costs. 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 for the Eastern District of Virginia for breach of contract as well as 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. In July 2015, the contractor filed a complaint against DTI in U.S. District Court for the Western District of Pennsylvania. In August 2015, DTI filed a motion to dismiss, or in the alternative, a motion to transfer venue to Virginia. This case is pending. DTI has accrued a liability of $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 and Landfill 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 Possum Point. 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 the 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 as settlement of the potential litigation. While the issue is open to potential further negotiations, the SELC declined the offer as presented in January 2015 and, in March 2015, filed a lawsuit related to its claims of the alleged CWA violations at Chesapeake. Virginia Power filed a motion to dismiss in April 2015, which was denied in November 2015. As a result of the December 2014 settlement offer, Virginia Power recognized a charge of $121 million in other operations and maintenance expense in its Consolidated Statements of Income in the Companies' Annual Report on Form 10-K for the year ended December 31, 2014. In April 2015, the EPA's final rule regulating the management of CCRs stored in impoundments (ash ponds) and landfills was published in the Federal Register. The final rule regulates CCR landfills, existing ash ponds that still receive and manage CCRs, and inactive ash ponds that do not receive, but still store CCRs. Virginia Power currently operates inactive ash ponds, existing ash ponds, and CCR landfills subject to the final rule at eight different facilities. The enactment of the final rule in April 2015 created a legal obligation for Virginia Power to retrofit or close all of its inactive and existing ash ponds over a certain period of time, as well as perform required monitoring, corrective action, and post-closure care activities as necessary. In 2015, Virginia Power recorded a $386 million ARO related to future ash pond and landfill closure costs. Recognition of the ARO also resulted in a $99 million incremental charge recorded in other operations and maintenance expense in its Consolidated Statement of Income, a $166 million increase in property, plant, and equipment associated with asset retirement costs, and a $121 million reduction in other noncurrent liabilities related to reversal of the contingent liability described above since the ARO obligation created by the final CCR rule represents similar activities. Virginia Power is in the process of obtaining the necessary permits to complete the work. The actual AROs related to the CCR rule may vary substantially from the estimates used to record the increased obligation in 2015. 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 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. In May 2015, FERC denied the requests for stay and rehearing. Two parties have separately filed petitions for review of the FERC order in the U.S. Court of Appeals for the D.C. Circuit, which petitions have been consolidated. Separately, one party requested a stay of the FERC order until the judicial proceedings are complete, which the court denied in June 2015. In May 2014, the Maryland Commission granted the CPCN authorizing the construction of a generating station in connection with the Liquefaction Project. The CPCN obligates Cove Point to make payments totaling $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 of Maryland. In February 2016, the Court of Special Appeals of Maryland issued an order affirming the judgment of the Circuit Court for Baltimore City in Maryland which affirmed the decision of the Maryland Commission granting the CPCN. 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 requiring 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 have been implemented. The information requests issued by the NRC request each reactor to reevaluate the seismic and external 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. The walkdowns of each unit have been completed, audited by the NRC and found to be adequate. Reevaluation of the seismic and external flooding hazards is expected to continue through 2018. Dominion and Virginia Power do not currently expect that compliance with the NRC’s information requests will materially impact their financial position, results of operations or cash flows during the 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 2015 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 2015 NRC minimum financial assurance amounts above were calculated using preliminary December 31, 2015 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 9 for additional information on nuclear decommissioning trust investments. Nuclear Insurance The Price-Anderson Amendments Act of 1988 provides the public up to $13.5 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. However, the NRC granted an exemption in March 2015 to remove Kewaunee from the Secondary Financial Protection program. The current levels of nuclear property insurance coverage for Dominion's and Virginia Power's nuclear units is as follows: Coverag

Credit Risk

Credit Risk	12 Months Ended
	Dec. 31, 2015
Risks and Uncertainties [Abstract]
Credit Risk	C REDIT R ISK 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, 2015 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, 2015, Dominion's credit exposure totaled $149 million . Of this amount, investment grade counterparties, including those internally rated, represented 79% , and no single counterparty, whether investment grade or non-investment grade, exceeded $31 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, 2015, 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 2015, DTI provided service to 266 customers with approximately 94% of its storage and transportation revenue being provided through firm services. The ten largest customers provided approximately 42% of the total storage and transportation revenue and the thirty largest provided approximately 72% of the total storage and transportation revenue. 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. East Ohio's 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, 2015 and 2014, Dominion would have been required to post an additional $12 million and $20 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 no collateral at December 31, 2015 and $1 million in collateral at December 31, 2014, 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, 2015 and 2014 was $49 million , 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, 2015 and 2014. See Note 7 for further information about derivative instruments.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2015
Related Party Transactions [Abstract]
Related-Party Transactions	R ELATED -P ARTY T RANSACTIONS 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. See Note 2 for further information. Dominion's transactions with equity method investments are described in Note 9. 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, 2015, Virginia Power's derivative assets and liabilities with affiliates were $13 million and $22 million , respectively. As of December 31, 2014, 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, 2015 and 2014, 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 $316 million and $219 million , respectively. At December 31, 2015 and 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 $77 million and $37 million , respectively. 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, 2015 2014 2013 (millions) Commodity purchases from affiliates $ 555 $ 543 $ 417 Services provided by affiliates (1) 422 432 415 Services provided to affiliates 22 22 21 (1) Includes capitalized expenditures. Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. There were $376 million and $427 million in short-term demand note borrowings from Dominion as of December 31, 2015 and 2014, respectively. Virginia Power had no outstanding borrowings, net of repayments under the Dominion money pool for its nonregulated subsidiaries as of December 31, 2015 and 2014. Interest charges related to Virginia Power's borrowings from Dominion were immaterial for the years ended December 31, 2015, 2014 and 2013. There were no issuances of Virginia Power's common stock to Dominion in 2015, 2014 or 2013. Dominion Gas Transactions with Related Parties 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, 2015 and 2014, 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, 2015 and 2014, 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 $652 million and $614 million , respectively. At December 31, 2015 and 2014, 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 $2 million and $7 million , respectively. DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to related parties, including technical services. The costs of these services follow: Year Ended December 31, 2015 2014 2013 (millions) Purchases of natural gas and transportation and storage services from affiliates $ 10 $ 34 $ 31 Sales of natural gas and transportation and storage services to affiliates 69 84 109 Services provided by related parties (1) 133 106 116 Services provided to related parties (2) 101 17 4 (1) Includes capitalized expenditures. (2) Amounts primarily attributable to Atlantic Coast Pipeline. The following table presents affiliated and related party activity reflected in Dominion Gas' Consolidated Balance Sheets: At December 31, 2015 2014 (millions) Other receivables (1) $ 7 $ 17 Customer receivables from related parties 4 5 Imbalances receivable from affiliates (2) 1 3 Affiliated notes receivable (3) 14 9 (1) Represents amounts due from Atlantic Coast Pipeline, a related party VIE. (2) Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets. (3) 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 $95 million and $384 million as of December 31, 2015 and 2014, respectively. Interest charges related to Dominion Gas' total borrowings from Dominion were immaterial for the year ended December 31, 2015 and $4 million and $35 million for the years ended December 31, 2014 and 2013, respectively.

Operating Segments

Operating Segments	12 Months Ended
	Dec. 31, 2015
Segment Reporting Information, Revenue for Reportable Segment [Abstract]
Operating Segments	O PERATING S EGMENTS 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 Segment Description of Operations Dominion Virginia Power Dominion Gas DVP Regulated electric distribution X X Regulated electric transmission X X Dominion Generation Regulated electric fleet X X Merchant electric fleet X Dominion Energy Gas transmission and storage X (1) X Gas distribution and storage X X Gas gathering and processing X X LNG import and storage X Nonregulated retail energy marketing (2) X (1) Includes remaining producer services activities. (2) As a result of Dominion's decision to realign its business units effective for 2015 year-end reporting, nonregulated retail energy marketing operations were moved from the Dominion Generation segment to the Dominion Energy segment. 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 March 2014, Dominion exited the electric retail energy marketing business. 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 2015, Dominion reported after-tax net expense of $391 million in the Corporate and Other segment, with $136 million of these net expenses attributable to specific items related to its operating segments. The net expenses for specific items in 2015 primarily related to the impact of the following items: • A $99 million ( $60 million after-tax) charge related to future ash pond and landfill closure costs at certain utility generation facilities, attributable to Dominion Generation; and • An $85 million ( $52 million after-tax) write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015, attributable to Dominion Generation. 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. The following table presents segment information pertaining to Dominion's operations: Year Ended December 31, DVP Dominion Generation (1) Dominion Energy (1) Corporate and Other Adjustments & Eliminations (1) Consolidated Total (millions) 2015 Total revenue from external customers $ 2,091 $ 7,001 $ 1,877 $ (27 ) $ 741 $ 11,683 Intersegment revenue 20 15 695 554 (1,284 ) — Total operating revenue 2,111 7,016 2,572 527 (543 ) 11,683 Depreciation, depletion and amortization 498 591 262 44 — 1,395 Equity in earnings of equity method investees — (15 ) 60 11 — 56 Interest income — 64 25 13 (44 ) 58 Interest and related charges 230 262 27 429 (44 ) 904 Income taxes 307 465 423 (290 ) — 905 Net income (loss) attributable to Dominion 490 1,120 680 (391 ) — 1,899 Investment in equity method investees — 245 1,042 33 — 1,320 Capital expenditures 1,607 2,190 2,153 43 — 5,993 Total assets (billions) 14.7 25.6 15.3 9.0 (5.8 ) 58.8 2014 Total revenue from external customers $ 1,918 $ 7,135 $ 2,446 $ (12 ) $ 949 $ 12,436 Intersegment revenue 18 34 880 572 (1,504 ) — Total operating revenue 1,936 7,169 3,326 560 (555 ) 12,436 Depreciation, depletion and amortization 462 514 243 73 — 1,292 Equity in earnings of equity method investees — (18 ) 54 10 — 46 Interest income — 58 23 20 (33 ) 68 Interest and related charges 205 240 11 770 (33 ) 1,193 Income taxes 317 365 463 (693 ) — 452 Net income (loss) attributable to Dominion 502 1,061 717 (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) 13.0 23.9 13.0 8.7 (4.3 ) 54.3 2013 Total revenue from external customers $ 1,825 $ 6,664 $ 3,566 $ 3 $ 1,062 $ 13,120 Intersegment revenue 9 283 739 609 (1,640 ) — Total operating revenue 1,834 6,947 4,305 612 (578 ) 13,120 Depreciation, depletion and amortization 427 511 235 35 — 1,208 Equity in earnings of equity method investees — (14 ) 21 7 — 14 Interest income — 59 19 42 (66 ) 54 Interest and related charges 175 220 26 522 (66 ) 877 Income taxes 287 436 456 (287 ) — 892 Loss from discontinued operations, net of tax — — — (92 ) — (92 ) Net income (loss) attributable to Dominion 475 963 711 (452 ) — 1,697 Capital expenditures 1,361 1,605 1,043 95 — 4,104 (1) Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment. 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 2015, Virginia Power reported after-tax net expenses of $153 million for specific items attributable to its operating segments in the Corporate and Other segment. The net expenses for specific items in 2015 primarily related to the impact of the following: • A $99 million ( $60 million after-tax) charge related to future ash pond and landfill closure costs at certain utility generation facilities, attributable to Dominion Generation; and • An $85 million ( $52 million after-tax) write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015, attributable to Dominion Generation. 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. The following table presents segment information pertaining to Virginia Power's operations: Year Ended December 31, DVP Dominion Generation Corporate and Other Adjustments & Eliminations Consolidated Total (millions) 2015 Operating revenue $ 2,099 $ 5,566 $ (43 ) $ — $ 7,622 Depreciation and amortization 498 453 2 — 953 Interest income — 7 — — 7 Interest and related charges 230 210 4 (1 ) 443 Income taxes 308 437 (86 ) 659 Net income (loss) 490 750 (153 ) — 1,087 Capital expenditures 1,569 1,120 — — 2,689 Total assets (billions) 14.7 17.0 — (0.1 ) 31.6 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 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 2015, Dominion Gas reported after-tax net expenses of $21 million in its Corporate and Other segment, with $13 million of these net expenses attributable to specific items related to its operating segment. The net expenses for specific items in 2015 primarily related to the impact of the following: • $16 million ( $10 million after-tax) ceiling test impairment charge. 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. The following table presents segment information pertaining to Dominion Gas' operations: Year Ended December 31, Dominion Energy Corporate and Other Consolidated Total (millions) 2015 Operating revenue $ 1,716 $ — $ 1,716 Depreciation and amortization 213 4 217 Equity in earnings of equity method investees 23 — 23 Interest income 1 — 1 Interest and related charges 72 1 73 Income taxes 296 (13 ) 283 Net income (loss) 478 (21 ) 457 Investment in equity method investees 102 — 102 Capital expenditures 795 — 795 Total assets (billions) 9.7 0.6 10.3 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 Capital expenditures 650 — 650

Quarterly Financial and Common

Quarterly Financial and Common Stock Data (Unaudited)	12 Months Ended
	Dec. 31, 2015
Selected Quarterly Financial Information [Abstract]
Quarterly Financial and Common Stock Data (Unaudited)	Q UARTERLY F INANCIAL AND C OMMON S TOCK D ATA ( UNAUDITED ) A summary of the Companies' quarterly results of operations for the years ended December 31, 2015 and 2014 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 Quarter Second Quarter Third Quarter Fourth Quarter Year (millions, except per share amounts) 2015 Operating revenue $ 3,409 $ 2,747 $ 2,971 $ 2,556 $ 11,683 Income from operations 1,002 773 1,123 638 3,536 Net income including noncontrolling interests 540 418 599 366 1,923 Income from continuing operations (1) 536 413 593 357 1,899 Net income attributable to Dominion 536 413 593 357 1,899 Basic EPS: Income from continuing operations (1) 0.91 0.70 1.00 0.60 3.21 Net income attributable to Dominion 0.91 0.70 1.00 0.60 3.21 Diluted EPS: Income from continuing operations (1) 0.91 0.70 1.00 0.60 3.20 Net income attributable to Dominion 0.91 0.70 1.00 0.60 3.20 Dividends declared per share 0.6475 0.6475 0.6475 0.6475 2.5900 Common stock prices (intraday high-low) $79.89 - 68.25 $74.34 - 66.52 $76.59 - 66.65 $74.88 - 64.54 $79.89 - 64.54 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 0.90 0.42 2.24 Net income attributable to Dominion 0.65 0.27 0.90 0.42 2.24 Dividends declared per share 0.60 0.60 0.60 0.60 2.40 Common stock prices (intraday high-low) $72.22 - $73.75 - $71.62 - 64.71 $80.89 - $80.89 - (1) Amounts attributable to Dominion's common shareholders. There were no significant items impacting Dominion's 2015 quarterly results. 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. Virginia Power Virginia Power's quarterly results of operations were as follows: First Quarter Second Quarter Third Quarter Fourth Quarter Year (millions) 2015 Operating revenue $ 2,137 $ 1,813 $ 2,058 $ 1,614 $ 7,622 Income from operations 525 481 741 374 2,121 Net income 269 246 385 187 1,087 Balance available for common stock 269 246 385 187 1,087 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 Virginia Power's 2015 results include the impact of the following significant items: • Fourth quarter results include a $32 million after-tax charge related to incremental future ash pond and landfill closure costs at certain utility generation facilities. • Second quarter results include a $28 million after-tax charge related to incremental future ash pond and landfill closure costs at certain utility generation facilities due to the enactment of the final CCR rule in April 2015. • First quarter results include a $52 million after-tax write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015. 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. Dominion Gas Dominion Gas' quarterly results of operations were as follows: First Quarter Second Quarter Third Quarter Fourth Quarter Year (millions) 2015 Operating revenue $ 531 $ 395 $ 365 $ 425 $ 1,716 Income from operations 271 153 202 163 789 Net income 161 85 111 100 457 2014 Operating revenue $ 569 $ 428 $ 391 $ 510 $ 1,898 Income from operations 265 154 177 255 851 Net income 164 93 107 148 512 Dominion Gas' 2015 results include the impact of the following significant items: • Third quarter results include a $29 million after-tax gain from an agreement to convey shale development rights underneath a natural gas storage field. • First quarter results include a $43 million after-tax gain from agreements to convey shale development rights underneath several natural gas storage fields. 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.

Significant Accounting Polici37

Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2015
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, 2015 and 2014 included $462 million and $564 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, 2015 and 2014 included $333 million and $407 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, 2015 and 2014 included $98 million and $127 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 FERC-regulated sales of gathering, transmission, distribution and storage services. Also included are state-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 FERC-regulated sales of gathering, transmission and storage services. Also included are state-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.
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. Current income taxes are based on taxable income or loss and credits determined on a separate company basis. Under the agreements, if a subsidiary incurs a tax loss or earns a credit, recognition of current income tax benefits is limited to refunds of prior year taxes obtained by the carryback of the net operating loss or credit or to the extent the tax loss or credit is absorbed by the taxable income of other Dominion consolidated group members. Otherwise, the net operating loss or credit 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 2015, 2014 and 2013. At December 31, 2015, Virginia Power's Consolidated Balance Sheet included a $296 million affiliated receivable, representing current year excess federal income tax payments expected to be refunded, $9 million of federal income taxes payable for prior years, less than $1 million of state income taxes payable, $10 million of state income taxes receivable, $14 million of noncurrent state income taxes receivable and $2 million of noncurrent state income taxes payable. 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. In March 2015, Virginia Power received a $229 million refund of its 2014 federal income tax payments. At December 31, 2015, Dominion Gas' Consolidated Balance Sheet included $91 million of affiliated receivables, representing current year excess federal income tax payments expected to be refunded and the benefit of utilizing a subsidiary’s tax loss to offset taxable income in Dominion’s consolidated tax return to be filed in 2016, less than $1 million of state income taxes payable, $4 million of state income taxes receivable and $22 million of noncurrent 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. In March 2015, Dominion Gas received a $93 million refund of its 2014 federal income tax payments. 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, 2015 2014 (millions) Dominion $27 $42 Virginia Power 11 20 Dominion Gas 7 9 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 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 $16 million and $287 million associated with cash collateral at December 31, 2015 and 2014, respectively. Dominion's margin liabilities associated with cash collateral at December 31, 2015 were immaterial. Dominion had margin liabilities of $34 million associated with cash collateral at December 31, 2014. Virginia Power did not have any margin assets associated with cash collateral at December 31, 2015. Virginia Power had margin assets of $6 million associated with cash collateral at December 31 2014. Virginia Power did not have any margin liabilities associated with cash collateral at December 31, 2015 or 2014. Dominion Gas did not have any margin assets or liabilities related to cash collateral at December 31, 2015 or 2014. 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 and interest 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. D ERIVATIVE I NSTRUMENTS D ESIGNATED AS H EDGING I NSTRUMENTS 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 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 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 2015, 2014 and 2013, Dominion capitalized interest costs and AFUDC to property, plant and equipment of $100 million , $80 million and $66 million , respectively. In 2015, 2014 and 2013, Virginia Power capitalized AFUDC to property, plant and equipment of $30 million , $39 million and $33 million , respectively. In 2015, 2014 and 2013, Dominion Gas capitalized AFUDC to property, plant and equipment of $1 million , $1 million and $5 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 2015, 2014 and 2013, Virginia Power recorded $19 million , $8 million and $32 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, 2015 2014 2013 (percent) Dominion Generation 2.78 2.66 2.71 Transmission 2.42 2.38 2.36 Distribution 3.11 3.12 3.13 Storage 2.42 2.39 2.43 Gas gathering and processing 3.19 2.81 2.39 General and other 3.67 3.62 3.82 Virginia Power Generation 2.78 2.66 2.71 Transmission 2.33 2.34 2.28 Distribution 3.33 3.34 3.33 General and other 3.40 3.29 3.51 Dominion Gas Transmission 2.46 2.40 2.43 Distribution 2.45 2.47 2.50 Storage 2.44 2.40 2.43 Gas gathering and processing 3.20 2.82 2.39 General and other 4.72 5.77 5.93 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, 2015, 2014 and 2013. 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.
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. Additionally, Virginia Power reports accretion of AROs and depreciation on asset retirement costs associated with certain prospective rider projects as an adjustment to the regulatory asset for certain jurisdictions. Accretion of all other AROs and depreciation of all other asset retirement costs are reported in other operations and maintenance expense and depreciation expense, respectively, 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. Amortization of the issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt securities prior to stated maturity dates are generally recognized and recorded in interest expense immediately. Effective January 2016, deferred debt issuance costs will be recorded as a reduction in long-term debt in the Consolidated Balance Sheets. 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 M ARKETABLE E QUITY AND D EBT S ECURITIES 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. N ON- M ARKETABLE I NVESTMENTS 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. O THER -T HAN -T EMPORARY I MPAIRMENT 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 $24 million and $12 million at December 31, 2015 and December 31, 2014, respectively. Based on the average price of gas purchased during 2015 and 2014, the cost of replacing the current portion of stored gas inventory exceeded the amount stated on a LIFO basis by $109 million and $98 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.
New Accounting Standards	New Accounting Standards In May 2014, the FASB issued revised accounting guidance for revenue recognition from contracts with customers. The core principle of this revised accounting guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amendments in this update also require disclosure of the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. For the Companies, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018. The Companies are currently in the preliminary stages of evaluating the impact of this guidance on their results of operations and overall liquidity. The Companies plan to complete their preliminary assessment, which includes a subset of representative contracts, in 2016. Once their initial evaluation is complete, the Companies will expand the scope of their assessment to include all contracts with customers. Other than increased disclosures, the impacts of the revised accounting guidance to the results of operations and cash flows of the Companies cannot be determined until their assessment process is complete. In November 2015, the FASB issued revised accounting guidance to simplify the presentation of deferred income taxes. This update requires that deferred tax liabilities and assets be classified as noncurrent in the Consolidated Balance Sheet. The Companies have adopted this guidance on a prospective basis for the period ended December 31, 2015. For prior periods, the Companies have presented deferred taxes in either the current or noncurrent sections of the Consolidated Balance Sheets based on the classification of the related financial accounting assets or liabilities, or, for items such as operating loss carryforwards, the period in which the deferred taxes were expected to reverse. In January 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of financial instruments. Most notably the update revises the accounting for equity securities, except for those accounted for under the equity method of accounting or resulting in consolidation, by requiring equity securities to be measured at fair value with the changes in fair value recognized in net income. However, an entity may measure equity investments that do not have a readily determinable fair value at cost minus impairment, if any, plus changes from observable price changes in orderly transactions for the identical or a similar investment of the same issuer. The guidance also simplifies the impairment assessment of equity investments without readily determinable fair values, revises the presentation of financial assets and liabilities and amends certain disclosure requirements associated with the fair value of financial instruments. The guidance is effective for the Companies’ interim and annual reporting periods beginning January 1, 2018, with a cumulative-effect adjustment to the balance sheet. Amendments related to equity securities without readily determinable fair values are to be applied prospectively to such investments that exist as of the date of adoption. The Companies are currently evaluating the impact the adoption of the standard will have on their consolidated financial statements and disclosures. In February 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of leasing arrangements. The update requires the recognition of lease assets and liabilities for those leases currently classified as operating leases while also refining the definition of a lease. In addition, lessees will be required to disclose key information about the amount, timing, and uncertainty of cash flows arising from leasing arrangements. The guidance is effective for the Companies’ interim and annual reporting periods beginning January 1, 2019, although it can be early adopted, with a modified retrospective approach for leases that commenced prior to the date of adoption. The Companies are currently evaluating the impact the adoption of the standard will have on their consolidated financial statements and disclosures.

Significant Accounting Polici38

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 2014 (millions) Dominion $27 $42 Virginia Power 11 20 Dominion Gas 7 9
Schedule of Depreciation Rates	The Companies' average composite depreciation rates on utility property, plant and equipment are as follows: Year Ended December 31, 2015 2014 2013 (percent) Dominion Generation 2.78 2.66 2.71 Transmission 2.42 2.38 2.36 Distribution 3.11 3.12 3.13 Storage 2.42 2.39 2.43 Gas gathering and processing 3.19 2.81 2.39 General and other 3.67 3.62 3.82 Virginia Power Generation 2.78 2.66 2.71 Transmission 2.33 2.34 2.28 Distribution 3.33 3.34 3.33 General and other 3.40 3.29 3.51 Dominion Gas Transmission 2.46 2.40 2.43 Distribution 2.45 2.47 2.50 Storage 2.44 2.40 2.43 Gas gathering and processing 3.20 2.82 2.39 General and other 4.72 5.77 5.93
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, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Schedule of Business Acquisitions, by Acquisition	The following table presents significant completed acquisitions of wholly-owned merchant solar projects by Dominion in 2014 and 2015. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for all of the projects. Dominion has claimed and/or expects to claim federal investment tax credits on the projects. These projects are included in the Dominion Generation operating segment. Completed Acquisition Date Seller Number of Projects Project Location Project Name(s) Initial Acquisition Cost (millions) (1) Project Cost (millions) (2) Date of Commercial Operations MW Capacity March 2014 Recurrent Energy Development Holdings, LLC 6 California Camelot, Kansas, Kent South, Old River One, Adams East, Columbia 2 $ 50 $ 428 Fourth quarter 2014 139 November 2014 CSI Project Holdco, LLC 1 California West Antelope 79 79 November 2014 20 December 2014 EDF Renewable Development, Inc. 1 California CID 71 71 January 2015 20 April 2015 EC&R NA Solar PV, LLC 1 California Alamo 66 66 May 2015 20 April 2015 EDF Renewable Development, Inc. 3 California Cottonwood (3) 106 106 May 2015 24 June 2015 EDF Renewable Development, Inc. 1 California Catalina 2 68 68 July 2015 18 July 2015 SunPeak Solar, LLC 1 California Imperial Valley 2 42 71 August 2015 20 November 2015 EC&R NA Solar PV, LLC 1 California Maricopa West 65 65 December 2015 20 November 2015 Community Energy, Inc. 1 Virginia Eastern Shore Solar 34 212 October 2016 80 (1) The purchase price was primarily allocated to Property, Plant and Equipment. (2) Includes acquisition cost. (3) One of the projects, Marin Carport, is expected to begin commercial operations in 2016.
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 (millions) Operating revenue $ 304 Loss before income taxes (135 ) (1) (1) Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013.

Operating Revenue (Tables)

Operating Revenue (Tables)	12 Months Ended
	Dec. 31, 2015
Regulated and Unregulated Operating Revenue [Abstract]
Operating Revenue, Table	The Companies' operating revenue consists of the following: Year Ended December 31, 2015 2014 2013 (millions) Dominion Electric sales: Regulated $ 7,482 $ 7,460 $ 7,193 Nonregulated 1,488 1,839 2,511 Gas sales: Regulated 218 334 323 Nonregulated 471 751 930 Gas transportation and storage 1,616 1,543 1,535 Other 408 509 628 Total operating revenue $ 11,683 $ 12,436 $ 13,120 Virginia Power Regulated electric sales $ 7,482 $ 7,460 $ 7,193 Other 140 119 102 Total operating revenue $ 7,622 $ 7,579 $ 7,295 Dominion Gas Gas sales: Regulated $ 122 $ 209 $ 202 Nonregulated 10 26 32 Gas transportation and storage 1,366 1,353 1,338 NGL revenue 93 212 292 Other 125 98 73 Total operating revenue $ 1,716 $ 1,898 $ 1,937

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 2014 2013 2015 2014 2013 2015 2014 2013 (millions) Current: Federal $ (24 ) $ (11 ) $ 317 $ 316 $ 85 $ 357 $ 90 $ 86 $ 158 State 75 14 110 92 67 62 30 32 41 Total current expense 51 3 427 408 152 419 120 118 199 Deferred: Federal Taxes before operating loss carryforwards and investment tax credits 384 956 563 154 381 224 156 192 92 Tax utilization (benefit) of operating loss carryforwards 539 (352 ) (18 ) 96 — — 6 — — Investment tax credits (134 ) (152 ) (48 ) (11 ) — — — — — State 66 (2 ) (31 ) 13 16 17 1 24 10 Total deferred expense 855 450 466 252 397 241 163 216 102 Amortization of deferred investment tax credits (1 ) (1 ) (1 ) (1 ) (1 ) (1 ) — — — Total income tax expense $ 905 $ 452 $ 892 $ 659 $ 548 $ 659 $ 283 $ 334 $ 301
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, 2015 2014 2013 2015 2014 2013 2015 2014 2013 U.S. statutory rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 3.7 — 2.1 3.9 3.8 3.1 2.7 4.4 4.3 Investment tax credits (4.7 ) (8.6 ) (1.8 ) (0.6 ) — — — — — Production tax credits (0.8 ) (1.2 ) (0.6 ) (0.6 ) (0.6 ) (0.2 ) — — — Valuation allowances (0.3 ) 0.7 (0.1 ) — — — — — — AFUDC - equity (0.3 ) — (0.6 ) (0.6 ) — (0.8 ) 0.2 — (0.1 ) Employee stock ownership plan deduction (0.6 ) (0.9 ) (0.6 ) — — — — — — Other, net — 0.4 (0.4 ) 0.6 0.8 (0.4 ) 0.3 0.1 0.3 Effective tax rate 32.0 % 25.4 % 33.0 % 37.7 % 39.0 % 36.7 % 38.2 % 39.5 % 39.5 %
The Companies deferred income taxes components	The Companies' deferred income taxes consist of the following: Dominion Virginia Power Dominion Gas At December 31, 2015 2014 2015 2014 2015 2014 (millions) Deferred income taxes: Total deferred income tax assets $ 1,152 $ 2,023 $ 164 $ 500 $ 129 $ 227 Total deferred income tax liabilities 8,552 8,663 4,805 4,915 2,343 2,289 Total net deferred income tax liabilities $ 7,400 $ 6,640 $ 4,641 $ 4,415 $ 2,214 $ 2,062 Total deferred income taxes: Plant and equipment, primarily depreciation method and basis differences $ 6,299 $ 5,895 $ 4,133 $ 3,965 $ 1,541 $ 1,417 Nuclear decommissioning 1,158 1,241 378 474 — — Deferred state income taxes 646 659 302 299 205 207 Federal benefit of deferred state income taxes (226 ) (231 ) (106 ) (105 ) (72 ) (72 ) Deferred fuel, purchased energy and gas costs (1 ) 27 (3 ) 18 1 7 Pension benefits 291 272 (99 ) (77 ) 613 567 Other postretirement benefits (15 ) (17 ) 30 13 (7 ) (12 ) Loss and credit carryforwards (1,004 ) (1,434 ) (53 ) (116 ) (4 ) (10 ) Valuation allowances 73 87 — — — — Partnership basis differences 367 304 — — 41 42 Other (188 ) (163 ) 59 (56 ) (104 ) (84 ) Total net deferred income tax liabilities $ 7,400 $ 6,640 $ 4,641 $ 4,415 $ 2,214 $ 2,062
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 2015 2014 2013 2015 2014 2013 2015 2014 2013 (millions) Balance at January 1 $ 145 $ 222 $ 293 $ 36 $ 39 $ 57 $ 29 $ 29 $ 30 Increases-prior period positions 2 24 17 — 2 12 — — — Decreases-prior period positions (40 ) (26 ) (99 ) (25 ) (16 ) (42 ) — — (1 ) Increases-current period positions 8 16 30 1 11 14 — — — Decreases-current period positions — — (5 ) — — — — — — Settlements with tax authorities (5 ) — (2 ) — — (2 ) — — — Expiration of statutes of limitations (7 ) (91 ) (12 ) — — — — — — Balance at December 31 $ 103 $ 145 $ 222 $ 12 $ 36 $ 39 $ 29 $ 29 $ 29
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 2012 Virginia (2) 2012 West Virginia (1) 2012 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 (millions) Current: Federal (274 ) State (41 ) Total current benefit (315 ) Deferred: Federal 232 State 40 Total deferred expense 272 Total income tax benefit (43 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Option, Quantitative Disclosures	The following table presents Dominion's quantitative information about Level 3 fair value measurements at December 31, 2015. 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) $ 97 Discounted Cash Flow Market Price (per Dth) (4) (2) - 8 (1 ) Credit Spread (5) 1% - 6% 3 % Liquids (3) 4 Discounted Cash Flow Market Price (per Gal) (4) 0 - 2 1 FTRs 9 Discounted Cash Flow Market Price (per MWh) (4) (2) - 14 1 Physical and Financial Options: Natural Gas 4 Option Model Market Price (per Dth) (4) 2 - 3 3 Price Volatility (6) 25% - 58% 37 % Total assets $ 114 Liabilities: Physical and Financial Forwards and Futures: Natural Gas (2) $ 9 Discounted Cash Flow Market Price (per Dth) (4) (2) - 3 2 FTRs 3 Discounted Cash Flow Market Price (per MWh) (4) (9) - 9 2 Physical and Financial Options: Natural Gas 7 Option Model Market Price (per Dth) (4) 2 - 5 3 Price Volatility (6) 25% - 58% 35 % Total liabilities $ 19 (1) Averages weighted by volume. (2) Includes basis. (3) Includes NGLs and oil. (4) Represents market prices beyond defined terms for Levels 1 and 2. (5) Represents credit spreads unrepresented in published markets. (6) Represents volatilities 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, 2015 Assets: Derivatives: Commodity $ 1 $ 249 $ 114 $ 364 Interest rate — 24 — 24 Investments (1) : Equity securities: U.S.: Large Cap 2,547 — — 2,547 Other 5 — — 5 REIT 63 — — 63 Non-U.S.: Large Cap 10 — — 10 Fixed Income: Corporate debt instruments — 437 — 437 U.S. Treasury securities and agency debentures 458 201 — 659 State and municipal — 376 — 376 Other — 100 — 100 Cash equivalents and other 2 2 — 4 Total assets $ 3,086 $ 1,389 $ 114 $ 4,589 Liabilities: Derivatives: Commodity $ — $ 141 $ 19 $ 160 Interest rate — 183 — 183 Total liabilities $ — $ 324 $ 19 $ 343 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 (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: 2015 2014 2013 (millions) Balance at January 1, $ 107 $ (16 ) $ 25 Total realized and unrealized gains (losses): Included in earnings (5 ) 97 (9 ) Included in other comprehensive income (loss) (9 ) 7 1 Included in regulatory assets/liabilities (4 ) 109 (9 ) Settlements 9 (88 ) (23 ) Transfers out of Level 3 (1) (3 ) (2 ) (1 ) Balance at December 31, $ 95 $ 107 $ (16 ) 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 $ 2 $ 6 $ — (1) In March 2015, Dominion changed the classification of certain short term NGL derivatives from Level 3 to Level 2 due to an increase in liquidity in financial forward markets. The transfers out of Level 3 that relate to NGLs for the year ended December 31, 2015 were $9 million .
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 (millions) Year Ended December 31, 2015 Total gains (losses) included in earnings $ 6 $ (11 ) $ — $ (5 ) 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 — 2 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 ) —
Schedule of Carrying Values and Estimated Fair Values of Debt 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, 2015 2014 Carrying Amount Estimated Fair Value (1) Carrying Amount Estimated Fair Value (1) (millions) Dominion Long-term debt, including securities due within one year (2) $ 21,998 $ 23,210 $ 19,723 $ 21,881 Junior subordinated notes (3) 1,358 1,192 1,374 1,396 Remarketable subordinated notes (3) 2,086 2,129 2,083 2,362 Virginia Power Long-term debt, including securities due within one year (3) $ 9,425 $ 10,400 $ 8,937 $ 10,293 Dominion Gas Long-term debt, including securities due within one year (3) $ 3,292 $ 3,299 $ 2,594 $ 2,672 (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, 2015, and 2014, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of $7 million and $19 million , respectively. (3) Carrying amount includes amounts which represent the unamortized discount and/or premium.
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, 2015. 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 $ 9 Discounted Cash Flow Market Price (per MWh) (3) (2) - 14 1 Natural gas (2) 92 Discounted Cash Flow Market Price (per Dth) (3) (2) - 4 (1 ) Credit Spread (4) 1% - 6% 3 % Total assets $ 101 Liabilities: Physical and Financial Forwards and Futures: FTRs $ 3 Discounted Cash Flow Market Price (per MWh) (3) (9) - 9 2 Physical and Financial Options: Natural gas 5 Discounted Cash Flow Market Price (per Dth) (3) 2 - 5 3 Price Volatility (5) 32% - 38% 35 % Total liabilities $ 8 (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. (5) Represents volatilities 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 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, 2015 Assets: Derivatives: Commodity $ — $ 13 $ 101 $ 114 Interest rate — 13 — 13 Investments (1) : Equity securities: U.S.: Large Cap 1,100 — — 1,100 REIT 63 — — 63 Fixed Income: Corporate debt instruments — 238 — 238 U.S. Treasury securities and agency debentures 180 79 — 259 State and municipal — 175 — 175 Other — 34 — 34 Total assets $ 1,343 $ 552 $ 101 $ 1,996 Liabilities: Derivatives: Commodity $ — $ 19 $ 8 $ 27 Interest rate — 59 — 59 Total liabilities $ — $ 78 $ 8 $ 86 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 (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: 2015 2014 2013 (millions) Balance at January 1, $ 102 $ (7 ) $ 2 Total realized and unrealized gains (losses): Included in earnings (13 ) 96 (17 ) Included in regulatory assets/liabilities (5 ) 109 (9 ) Settlements 13 (96 ) 17 Transfers out of Level 3 (4 ) — — Balance at December 31, $ 93 $ 102 $ (7 )
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Option, Quantitative Disclosures	The following table presents Dominion Gas' quantitative information about Level 3 fair value measurements at December 31, 2015. 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: NGLs $ 6 Discounted Cash Flow Market Price (per Gal) (2) 0 - 1 1 Total assets $ 6 (1) Averages weighted by volume. (2) Represents market prices beyond defined terms for Levels 1 and 2.
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, 2015 Assets: Commodity $ — $ 5 $ 6 $ 11 Total assets $ — $ 5 $ 6 $ 11 Liabilities: Interest rate $ — $ 14 $ — $ 14 Total liabilities $ — $ 14 $ — $ 14 At December 31, 2014 Assets: Commodity $ — $ — $ 2 $ 2 Total assets $ — $ — $ 2 $ 2 Liabilities: Interest rate $ — $ 9 $ — 9 Total liabilities $ — $ 9 $ — $ 9
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: 2015 2014 2013 (millions) Balance at January 1, $ 2 $ (6 ) $ (12 ) Total realized and unrealized gains (losses): Included in earnings 1 2 1 Included in other comprehensive income (loss) (5 ) 10 3 Settlements (1 ) (4 ) 2 Transfers out of Level 3 (1) 9 — — Balance at December 31, $ 6 $ 2 $ (6 ) (1) In March 2015, Dominion Gas changed the classification of certain short term NGL derivatives from Level 3 to Level 2 due to an increase in liquidity in financial forward markets. The transfers out of Level 3 that relate to NGLs for the year ended December 31, 2015 were $9 million .

Derivatives and Hedge Account43

Derivatives and Hedge Accounting Activities (Tables)	12 Months Ended
	Dec. 31, 2015
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: December 31, 2015 December 31, 2014 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 $ 24 $ — $ 24 Commodity contracts: Over-the-counter 217 — 217 382 — 382 Exchange 138 — 138 298 — 298 Total derivatives, subject to a master netting or similar arrangement 379 — 379 704 — 704 Total derivatives, not subject to a master netting or similar arrangement 9 — 9 15 — 15 Total $ 388 $ — $ 388 $ 719 $ — $ 719 December 31, 2015 December 31, 2014 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 $ 22 $ — $ 2 $ 24 $ 16 $ — $ 8 Commodity contracts: Over-the-counter 217 37 — 180 382 34 34 314 Exchange 138 82 — 56 298 298 — — Total $ 379 $ 141 $ — $ 238 $ 704 $ 348 $ 34 $ 322
Offsetting Liabilities	December 31, 2015 December 31, 2014 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 $ 183 $ — $ 183 $ 202 $ — $ 202 Commodity contracts: Over-the-counter 70 — 70 87 — 87 Exchange 82 — 82 493 — 493 Total derivatives, subject to a master netting or similar arrangement 335 — 335 782 — 782 Total derivatives, not subject to a master netting or similar arrangement 8 — 8 12 — 12 Total $ 343 $ — $ 343 $ 794 $ — $ 794 December 31, 2015 December 31, 2014 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 $ 183 $ 22 $ — $ 161 $ 202 $ 16 $ — $ 186 Commodity contracts: Over-the-counter 70 37 — 33 87 34 1 52 Exchange 82 82 — — 493 298 195 — Total $ 335 $ 141 $ — $ 194 $ 782 $ 348 $ 196 $ 238
Volumes of Derivatives	The following table presents the volume of Dominion's derivative activity as of December 31, 2015. 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) 80 19 Basis 216 554 Electricity (MWh): Fixed price 15,661,078 — FTRs 33,350,993 — Capacity (MW) 7,600 — Liquids (Gal) (2) 83,076,000 18,606,000 Interest rate $ 2,950,000,000 $ 3,100,000,000 (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, 2015: AOCI Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax Maximum (millions) Commodities: Gas $ (7 ) $ (7 ) 22 months Electricity 76 76 12 months Other 6 6 15 months Interest rate (251 ) (9 ) 387 months Total $ (176 ) $ 66
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 (millions) At December 31, 2015 ASSETS Current Assets Commodity $ 101 $ 151 $ 252 Interest rate 3 — 3 Total current derivative assets 104 151 255 Noncurrent Assets Commodity 3 109 112 Interest rate 21 — 21 Total noncurrent derivative assets (1) 24 109 133 Total derivative assets $ 128 $ 260 $ 388 LIABILITIES Current Liabilities Commodity $ 32 $ 116 $ 148 Interest rate 164 — 164 Total current derivative liabilities 196 116 312 Noncurrent Liabilities Commodity — 12 12 Interest rate 19 — 19 Total noncurrent derivative liabilities (2) 19 12 31 Total derivative liabilities $ 215 $ 128 $ 343 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 (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 (1) Amount of Increase (2) (millions) Year Ended December 31, 2015 Derivative Type and Location of Gains (Losses) Commodity: Operating revenue $ 203 Purchased gas (15 ) Electric fuel and other energy-related purchases (1 ) Total commodity $ 230 $ 187 $ 4 Interest rate (3) (46 ) (11 ) (13 ) Total $ 184 $ 176 $ (9 ) 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 (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) Year Ended December 31, 2015 2014 2013 (millions) Derivative Type and Location of Gains (Losses) Commodity: Operating revenue $ 24 $ (310 ) $ (45 ) Purchased gas (14 ) (51 ) (9 ) Electric fuel and other energy-related purchases (14 ) 113 (29 ) Interest rate (2) (1 ) — — Total $ (5 ) $ (248 ) $ (83 ) (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: December 31, 2015 December 31, 2014 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 $ 13 $ — $ 13 $ — $ — $ — Commodity contracts: Over-the-counter 101 — 101 106 — 106 Total derivatives, subject to a master netting or similar arrangement 114 — 114 106 — 106 Total derivatives, not subject to a master netting or similar arrangement 13 — 13 7 — 7 Total $ 127 $ — $ 127 $ 113 $ — $ 113 December 31, 2015 December 31, 2014 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 $ 13 $ 10 $ — $ 3 $ — $ — $ — $ — Commodity contracts: Over-the-counter 101 3 — 98 106 4 — 102 Total $ 114 $ 13 $ — $ 101 $ 106 $ 4 $ — $ 102
Offsetting Liabilities	December 31, 2015 December 31, 2014 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 $ 59 $ — $ 59 $ 72 $ — $ 72 Commodity contracts: Over-the-counter 5 — 5 8 — 8 Total derivatives, subject to a master netting or similar arrangement 64 — 64 80 — 80 Total derivatives, not subject to a master netting or similar arrangement 22 — 22 7 — 7 Total $ 86 $ — $ 86 $ 87 $ — $ 87 December 31, 2015 December 31, 2014 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 $ 59 $ 10 $ — $ 49 $ 72 $ — $ — $ 72 Commodity contracts: Over-the-counter 5 3 — 2 8 4 — 4 Total $ 64 $ 13 $ — $ 51 $ 80 $ 4 $ — $ 76
Volumes of Derivatives	The following table presents the volume of Virginia Power's derivative activity at December 31, 2015. 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) 32 10 Basis 102 509 Electricity (MWh): FTRs 30,383,934 — Capacity (MW) 7,600 — Interest rate $ 900,000,000 $ 1,100,000,000 (1) Includes options.
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 - Derivatives under Hedge Accounting Fair Value - Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2015 ASSETS Current Assets Commodity $ — $ 18 $ 18 Total current derivative assets (1) — 18 18 Noncurrent Assets Commodity — 96 96 Interest rate 13 — 13 Total noncurrent derivative assets (2) 13 96 109 Total derivative assets $ 13 $ 114 $ 127 LIABILITIES Current Liabilities Commodity $ — $ 23 $ 23 Interest rate 57 — 57 Total current derivative liabilities 57 23 80 Noncurrent Liabilities Commodity — 4 4 Interest rate 2 — 2 Total noncurrent derivative liabilities (3) 2 4 6 Total derivative liabilities $ 59 $ 27 $ 86 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 (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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified from AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Year Ended December 31, 2015 Derivative Type and Location of Gains (Losses) Commodity: Electric fuel and other energy-related purchases $ (1 ) Total commodity $ — $ (1 ) $ 4 Interest rate (3) (3 ) — (13 ) Total $ (3 ) $ (1 ) $ (9 ) 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 (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 instruments Amount of Gain (Loss) Recognized in Income on Derivatives (1) Year Ended December 31, 2015 2014 2013 (millions) Derivative Type and Location of Gains (Losses) Commodity (2) $ (13 ) $ 105 $ (16 ) Total $ (13 ) $ 105 $ (16 ) (1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power's Consolidated Statements of Income. (2) Amounts 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: December 31, 2015 December 31, 2014 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) Commodity contracts: Over-the-counter $ 11 $ — $ 11 $ 2 $ — $ 2 Total derivatives, subject to a master netting or similar arrangement $ 11 $ — $ 11 $ 2 $ — $ 2 December 31, 2015 December 31, 2014 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) Commodity contracts: Over-the-counter $ 11 $ — $ — $ 11 $ 2 $ — $ — $ 2 Total $ 11 $ — $ — $ 11 $ 2 $ — $ — $ 2
Offsetting Liabilities	December 31, 2015 December 31, 2014 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 $ 14 $ — $ 14 $ 9 $ — $ 9 Total derivatives, subject to a master netting or similar arrangement $ 14 $ — $ 14 $ 9 $ — $ 9 December 31, 2015 December 31, 2014 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 $ 14 $ — $ — $ 14 $ 9 $ — $ — $ 9 Total $ 14 $ — $ — $ 14 $ 9 $ — $ — $ 9
Volumes of Derivatives	The following table presents the volume of Dominion Gas' derivative activity at December 31, 2015. 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 (Gal) 77,364,000 13,818,000 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, 2015: AOCI Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax Maximum (millions) Commodities: NGLs $ 7 $ 6 15 months Interest rate (24 ) — 348 months Total $ (17 ) $ 6
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 - Derivatives under Hedge Accounting Fair Value - Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2015 ASSETS Current Assets Commodity $ 10 $ — $ 10 Total current derivative assets (1) 10 — 10 Noncurrent Assets Commodity 1 — 1 Total noncurrent derivative assets (2) 1 — 1 Total derivative assets $ 11 $ — $ 11 LIABILITIES Current Liabilities Interest rate $ 14 $ — $ 14 Total current derivative liabilities (3) 14 — 14 Total derivative liabilities $ 14 $ — $ 14 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 (4) 9 — 9 Total derivative liabilities $ 9 $ — $ 9 (1) Current derivative assets are presented in other current assets in Dominion Gas' Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other 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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified from AOCI to Income (millions) Year Ended December 31, 2015 Derivative Type and Location of Gains (Losses) Commodity: Operating revenue $ 6 Total commodity $ 16 $ 6 Interest rate (2) (6 ) — Total $ 10 $ 6 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 ) (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.
Schedule Of Derivatives Not Designated As Hedging Instruments	Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized in Income on Derivatives Year Ended December 31, 2015 2014 2013 (millions) Derivative Type and Location of Gains (Losses) Commodity Operating revenue $ 6 $ — $ — Total $ 6 $ — $ —

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share Computation	The following table presents the calculation of Dominion's basic and diluted EPS: 2015 2014 2013 (millions, except EPS) Net income attributable to Dominion $ 1,899 $ 1,310 $ 1,697 Average shares of common stock outstanding-Basic 592.4 582.7 578.7 Net effect of dilutive securities (1) 1.3 1.8 0.8 Average shares of common stock outstanding-Diluted 593.7 584.5 579.5 Earnings Per Common Share-Basic $ 3.21 $ 2.25 $ 2.93 Earnings Per Common Share-Diluted $ 3.20 $ 2.24 $ 2.93 (1) Dilutive securities consist primarily of the 2013 Equity Units for 2015, the 2013 Equity Units and contingently convertible senior notes for 2014, and contingently convertible senior notes for 2013. 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, 2015
Schedule of Available-for-sale Securities [Line Items]
Available-For-Sale Securities	Dominion's decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains (1) Total Unrealized Losses (1) Fair Value (millions) At December 31, 2015 Marketable equity securities: U.S. large cap $ 1,295 $ 1,213 $ — $ 2,508 REIT 59 4 — 63 Marketable debt securities: Corporate debt instruments 433 11 (7 ) 437 U.S. Treasury securities and agency debentures 654 8 (4 ) 658 State and municipal 312 22 — 334 Other 99 — — 99 Cost method investments 70 — — 70 Cash equivalents and other (2) 14 — — 14 Total $ 2,936 $ 1,258 $ (11 ) (3) $ 4,183 At December 31, 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 (1) Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Includes pending sales of securities of $12 million and $3 million at December 31, 2015 and 2014, respectively. (3) The fair value of securities in an unrealized loss position was $592 million and $379 million at December 31, 2015 and 2014, 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, 2015 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 208 Due after one year through five years 396 Due after five years through ten years 412 Due after ten years 512 Total $ 1,528
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, 2015 2014 2013 (millions) Proceeds from sales $ 1,340 $ 1,235 $ 1,476 Realized gains (1) 219 171 157 Realized losses (1) 84 30 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, 2015 2014 2013 (millions) Total other-than-temporary impairment losses (1) $ 66 $ 21 $ 31 Losses recorded to nuclear decommissioning trust regulatory liability (26 ) (5 ) (13 ) Losses recognized in other comprehensive income (before taxes) (9 ) (3 ) (10 ) Net impairment losses recognized in earnings $ 31 $ 13 $ 8 (1) Amounts include other-than-temporary impairment losses for debt securities of $9 million , $3 million and $18 million at December 31, 2015, 2014 and 2013, 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, 2015 2014 (millions) Dominion Blue Racer 50 % $ 661 $ 671 Midstream gas and related services Iroquois 50.65 % (1) 324 107 Gas transmission system Fowler Ridge 50 % 125 134 Wind-powered merchant generation facility NedPower 50 % 119 128 Wind-powered merchant generation facility Atlantic Coast Pipeline 45 % 59 19 Gas transmission system Other (2) various 32 22 Total $ 1,320 $ 1,081 Dominion Gas Iroquois 24.72 % $ 102 $ 107 Gas transmission system Total $ 102 $ 107 (1) Comprised of Dominion Midstream's interest of 25.93% and Dominion Gas' interest of 24.72% . See Note 15 for more information. (2) Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018.
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 Cost Total Unrealized Gains (1) Total Unrealized Losses (1) Fair Value (millions) At December 31, 2015 Marketable equity securities: U.S. large cap $ 574 $ 525 $ — $ 1,099 REIT 59 4 — 63 Marketable debt securities: Corporate debt instruments 237 5 (4 ) 238 U.S. Treasury securities and agency debentures 260 1 (2 ) 259 State and municipal 162 13 (1 ) 174 Other 34 — — 34 Cost method investments 70 — — 70 Cash equivalents and other (2) 8 — — 8 Total $ 1,404 $ 548 $ (7 ) (3) $ 1,945 At December 31, 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 (1) Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Includes pending sales of securities of $8 million and $6 million at December 31, 2015 and 2014, respectively. (3) The fair value of securities in an unrealized loss position was $281 million and $170 million at December 31, 2015 and 2014, respectively.
Investments Classified by Contractual Maturity Date	The fair value of Virginia Power's marketable debt securities at December 31, 2015, by contractual maturity is as follows: Amount (millions) Due in one year or less $ 67 Due after one year through five years 166 Due after five years through ten years 236 Due after ten years 236 Total $ 705
Marketable Securities	Presented below is selected information regarding Virginia Power's marketable equity and debt securities held in nuclear decommissioning trust funds. Year Ended December 31, 2015 2014 2013 (millions) Proceeds from sales $ 639 $ 549 $ 572 Realized gains (1) 110 73 52 Realized losses (1) 43 12 14 (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 held in nuclear decommissioning trust funds as follows: Year Ended December 31, 2015 2014 2013 (millions) Total other-than-temporary impairment losses (1) $ 36 $ 8 $ 15 Losses recorded to nuclear decommissioning trust regulatory liability (26 ) (4 ) (13 ) Losses recorded in other comprehensive income (before taxes) (6 ) (2 ) (1 ) Net impairment losses recognized in earnings $ 4 $ 2 $ 1 (1) Amounts include other-than-temporary impairment losses for debt securities of $6 million , $2 million and $9 million at December 31, 2015, 2014 and 2013, respectively.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 2014 (millions) Dominion Utility: Generation $ 15,656 $ 15,193 Transmission 11,461 9,897 Distribution 13,128 12,354 Storage 2,460 2,350 Nuclear fuel 1,464 1,411 Gas gathering and processing 799 791 General and other 927 845 Other-including plant under construction 5,550 3,633 Total utility 51,445 46,474 Nonutility: Merchant generation-nuclear 1,339 1,267 Merchant generation-other 2,683 2,023 Nuclear fuel 938 860 Other-including plant under construction 1,371 782 Total nonutility 6,331 4,932 Total property, plant and equipment $ 57,776 $ 51,406 Virginia Power Utility: Generation $ 15,656 $ 15,193 Transmission 6,963 5,884 Distribution 10,048 9,526 Nuclear fuel 1,464 1,411 General and other 709 697 Other-including plant under construction 2,793 2,464 Total utility 37,633 35,175 Nonutility-other 6 5 Total property, plant and equipment $ 37,639 $ 35,180 Dominion Gas Utility: Transmission $ 3,804 $ 3,690 Distribution 2,765 2,530 Storage 1,583 1,466 Gas gathering and processing 797 786 General and other 165 111 Plant under construction 443 179 Total utility 9,557 8,762 Nonutility: E&P properties being amortized and other 136 140 Total nonutility 136 140 Total property, plant and equipment $ 9,693 $ 8,902
Share of Jointly-Owned Power Stations	Dominion's and Virginia Power's proportionate share of jointly-owned power stations at December 31, 2015 is as follows: Bath County Pumped Storage Station (1) North Anna Units 1 and 2 (1) Clover Power Station (1) Millstone Unit 3 (2) (millions, except percentages) Ownership interest 60 % 88.4 % 50 % 93.5 % Plant in service $ 1,049 $ 2,452 $ 576 $ 1,149 Accumulated depreciation (567 ) (1,177 ) (214 ) (320 ) Nuclear fuel — 621 — 521 Accumulated amortization of nuclear fuel — (502 ) — (364 ) Plant under construction 12 116 16 55 (1) Units jointly owned by Virginia Power. (2) Unit jointly owned by Dominion.

Goodwill And Intangible Assets

Goodwill And Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2015
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 Generation Dominion Energy DVP Corporate and Other (1) Total (millions) Dominion Balance at December 31, 2013 (2) $ 1,454 (3) $ 706 (3) $ 926 $ — $ 3,086 Asset disposition adjustment (32 ) (4) (10 ) (5) — — (42 ) Balance at December 31, 2014 (2) $ 1,422 (3) $ 696 (3) $ 926 $ — $ 3,044 DCG acquisition — 250 — — 250 Balance at December 31, 2015 (2) $ 1,422 $ 946 $ 926 $ — $ 3,294 Dominion Gas Balance at December 31, 2013 (2) $ — $ 545 $ — $ — $ 545 Asset disposition adjustment — (3 ) (5) — — (3 ) Balance at December 31, 2014 (2) $ — $ 542 $ — $ — $ 542 No events affecting goodwill — — — — — Balance at December 31, 2015 (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) Recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment. (4) See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs. (5) 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, 2015 2014 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization (millions) Dominion Software, licenses and other $ 942 $ 372 $ 887 $ 317 Total $ 942 $ 372 $ 887 $ 317 Virginia Power Software, licenses and other $ 301 $ 88 $ 286 $ 81 Total $ 301 $ 88 $ 286 $ 81 Dominion Gas Software, licenses and other $ 211 $ 128 $ 192 $ 113 Total $ 211 $ 128 $ 192 $ 113
Annual amortization expense of intangible assets	Annual amortization expense for these intangible assets is estimated to be as follows: 2016 2017 2018 2019 2020 (millions) Dominion $ 79 $ 68 $ 57 $ 47 $ 35 Virginia Power $ 25 $ 22 $ 19 $ 15 $ 9 Dominion Gas $ 18 $ 15 $ 14 $ 13 $ 13

Regulatory Assets and Liabili48

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets and Liabilities	Regulatory assets and liabilities include the following: At December 31, 2015 2014 (millions) Dominion Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 111 $ 79 Deferred rate adjustment clause costs (2) 90 124 Deferred nuclear refueling outage costs (3) 75 44 Unrecovered gas costs (4) 12 36 Other 63 64 Regulatory assets-current 351 347 Unrecognized pension and other postretirement benefit costs (5) 1,015 1,050 Deferred rate adjustment clause costs (2) 295 250 PJM transmission rates (6) 192 — Income taxes recoverable through future rates (7) 126 133 Derivatives (8) 110 101 Other 127 108 Regulatory assets-non-current 1,865 1,642 Total regulatory assets $ 2,216 $ 1,989 Regulatory liabilities: PIPP (9) $ 46 $ 71 Other 54 99 Regulatory liabilities-current (10) 100 170 Provision for future cost of removal and AROs (11) 1,120 1,072 Nuclear decommissioning trust (12) 804 815 Deferred cost of fuel used in electric generation (1) 97 6 Derivatives (8) 79 — Other 185 98 Regulatory liabilities-non-current 2,285 1,991 Total regulatory liabilities $ 2,385 $ 2,161 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 111 $ 79 Deferred rate adjustment clause costs (2) 80 117 Deferred nuclear refueling outage costs (3) 75 44 Other 60 58 Regulatory assets-current 326 298 Deferred rate adjustment clause costs (2) 213 179 PJM transmission rates (6) 192 — Derivatives (8) 110 101 Income taxes recoverable through future rates (7) 97 100 Other 55 59 Regulatory assets-non-current 667 439 Total regulatory assets $ 993 $ 737 Regulatory liabilities: Other $ 35 $ 90 Regulatory liabilities-current 35 90 Provision for future cost of removal (11) 890 852 Nuclear decommissioning trust (12) 804 815 Deferred cost of fuel used in electric generation (1) 97 6 Derivatives (8) 79 — Other 59 10 Regulatory liabilities-non-current 1,929 1,683 Total regulatory liabilities $ 1,964 $ 1,773 Dominion Gas Regulatory assets: Unrecovered gas costs (4) $ 11 $ 29 Deferred rate adjustment clause costs (2) 10 7 Other 2 2 Regulatory assets-current 23 38 Unrecognized pension and other postretirement benefit costs (5) 282 242 Deferred rate adjustment clause costs (2) 82 71 Income taxes recoverable through future rates (7) 20 24 Other 65 42 Regulatory assets-non-current 449 379 Total regulatory assets $ 472 $ 417 Regulatory liabilities: PIPP (9) $ 46 $ 71 Other 9 4 Regulatory liabilities-current 55 75 Provision for future cost of removal and AROs (11) 170 172 Other 31 20 Regulatory liabilities-non-current 201 192 Total regulatory liabilities $ 256 $ 267 (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. (2) 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. (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 and Dominion Gas' rate-regulated subsidiaries. (6) Reflects amount related to the PJM transmission cost allocation matter. See Note 13 for more information. (7) Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes. (8) 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. (9) 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 rate adjustment clause according to East Ohio tariff provisions. See Note 13 for more information. (10) Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets. (11) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (12) Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power’s utility nuclear generation stations, in excess of the related AROs.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation [Abstract]
Changes to Asset Retirement Obligations	The changes to AROs during 2014 and 2015 were as follows: Amount (millions) Dominion AROs at December 31, 2013 $ 1,578 Obligations incurred during the period 40 Obligations settled during the period (82 ) Revisions in estimated cash flows (1) 102 Accretion 81 Other (5 ) AROs at December 31, 2014 (2) $ 1,714 Obligations incurred during the period (3) 315 Obligations settled during the period (106 ) Revisions in estimated cash flows (3) 88 Accretion 93 Other (1 ) AROs at December 31, 2015 (2) $ 2,103 Virginia Power AROs at December 31, 2013 $ 689 Obligations incurred during the period 28 Obligations settled during the period (1 ) Revisions in estimated cash flows (1) 108 Accretion 37 Other (6 ) AROs at December 31, 2014 $ 855 Obligations incurred during the period (3) 289 Obligations settled during the period (39 ) Revisions in estimated cash flows (3) 92 Accretion 50 AROs at December 31, 2015 $ 1,247 Dominion Gas AROs at December 31, 2013 $ 137 Obligations incurred during the period 2 Obligations settled during the period (8 ) Accretion 8 Other 8 AROs at December 31, 2014 (4) $ 147 Obligations incurred during the period 5 Obligations settled during the period (6 ) Revisions in estimated cash flows (5 ) Accretion 9 Other (1 ) AROs at December 31, 2015 (4) $ 149 (1) Relates primarily to a shift of the delayed planned date on which the DOE is expected to begin accepting spent nuclear fuel. (2) Includes $81 million and $216 million reported in other current liabilities at December 31, 2014, and 2015, respectively. (3) Primarily reflects future ash pond and landfill closure costs at certain utility generation facilities. See Note 22 for further information. (4) Includes $140 million and $137 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2014 and 2015, respectively.

Short-Term Debt And Credit Ag50

Short-Term Debt And Credit Agreements (Tables)	12 Months Ended
	Dec. 31, 2015
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 Limit Outstanding Outstanding Facility (millions) At December 31, 2015 Joint revolving credit facility (1)(2) $ 4,000 $ 3,353 $ — $ 647 Joint revolving credit facility (1) 500 156 59 285 Total $ 4,500 $ 3,509 (3) $ 59 $ 932 At December 31, 2014 Joint revolving credit facility (1) $ 4,000 $ 2,664 $ — $ 1,336 Joint revolving credit facility (1) 500 111 48 341 Total $ 4,500 $ 2,775 (3) $ 48 $ 1,677 (1) These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to a combined $2.0 billion of letters of credit. (2) In January 2016, this facility limit was increased from $4.0 billion to $5.0 billion . (3) The weighted-average interest rates of the outstanding commercial paper supported by Dominion’s credit facilities were 0.62% and 0.38% at December 31, 2015 and 2014, 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 under its joint credit facilities with Dominion and Dominion Gas were as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) At December 31, 2015 Joint revolving credit facility (1)(2) $ 4,000 $ 1,500 $ — Joint revolving credit facility (1) 500 156 — Total $ 4,500 $ 1,656 (3) $ — At December 31, 2014 Joint revolving credit facility (1) $ 4,000 $ 1,250 $ — Joint revolving credit facility (1) 500 111 — Total $ 4,500 $ 1,361 (3) $ — (1) The full amount of the facilities is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion and Dominion Gas. Sub-limits for Virginia Power are set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2015, the sub-limit for Virginia Power was an aggregate $1.75 billion . If Virginia Power has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion. These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $2.0 billion (or the sub-limit, whichever is less) of letters of credit. (2) In January 2016, this facility limit was increased from $4.0 billion to $5.0 billion . (3) The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.60% and 0.36% at December 31, 2015 and 2014, respectively.
Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Commercial paper bank loans and letters of credit outstanding as well as capacity available under credit facilities	Dominion Gas' share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Virginia Power were as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) At December 31, 2015 Joint revolving credit facility (1) $ 1,000 $ 391 $ — Joint revolving credit facility (1) 500 — — Total $ 1,500 $ 391 (2) $ — At December 31, 2014 Joint revolving credit facility (1) $ 1,000 $ — $ — Joint revolving credit facility (1) 500 — — Total $ 1,500 $ — $ — (1) A maximum of a combined $1.5 billion of the facilities is available to Dominion Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion and Virginia Power. Sub-limits for Dominion Gas are set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2015, the sub-limit for Dominion Gas was an aggregate $500 million . In January 2016, the aggregate sub-limit for Dominion Gas was increased to $1.0 billion . If Dominion Gas has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion. These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (or the sub-limit, whichever is less) of letters of credit. (2) The weighted-average interest rate of the outstanding commercial paper supported by these credit facilities was 0.63% at December 31, 2015.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Long-term Debt, Unclassified [Abstract]
Long term Debt	At December 31, 2015 Weighted- average Coupon (1) 2015 2014 (millions, except percentages) Dominion Gas Holdings, LLC: Unsecured Senior Notes: 1.05% to 2.8%, due 2016 to 2020 2.26 % $ 1,550 $ 850 3.55% to 4.8%, due 2023 to 2044 4.15 % 1,750 1,750 Dominion Gas Holdings, LLC total principal $ 3,300 $ 2,600 Securities due within one year 1.05 % (400 ) Unamortized discount (8 ) (6 ) Dominion Gas Holdings, LLC total long-term debt $ 2,892 $ 2,594 Virginia Electric and Power Company: Unsecured Senior Notes: 1.2% to 8.625%, due 2015 to 2019 5.03 % $ 2,261 $ 2,471 2.75% to 8.875%, due 2022 to 2045 4.91 % 6,292 5,592 Tax-Exempt Financings (2) : Variable rates, due 2016 to 2041 0.79 % 194 606 0.70% to 5.6%, due 2023 to 2041 2.19 % 678 266 Virginia Electric and Power Company total principal $ 9,425 $ 8,935 Securities due within one year 5.24 % (476 ) (211 ) Unamortized discount and premium, net — 2 Virginia Electric and Power Company total long-term debt $ 8,949 $ 8,726 Dominion Resources, Inc.: Unsecured Senior Notes: Variable rates, due 2015 and 2016 1.11 % $ 600 $ 400 1.25% to 6.4%, due 2015 to 2019 3.05 % 3,400 3,150 2.75% to 7.0%, due 2021 to 2044 (3) 4.80 % 5,099 4,449 Tax-Exempt Financing, variable rate, due 2041 1.16 % 75 75 Unsecured Junior Subordinated Notes Payable to Affiliated Trust, 8.4%, due 2031 8.40 % 10 10 Enhanced Junior Subordinated Notes: 5.75% and 7.5%, due 2054 and 2066 6.27 % 971 985 Variable rate, due 2066 2.90 % 377 380 Remarketable Subordinated Notes, 1.07% to 1.50%, due 2019 to 2021 1.30 % 2,100 2,100 Unsecured Debentures and Senior Notes (4) : 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) 3,300 2,600 Virginia Electric and Power Company total principal (from above) 9,425 8,935 Dominion Resources, Inc. total principal $ 25,473 $ 23,200 Fair value hedge valuation (5) 7 19 Securities due within one year (6) 2.38 % (1,826 ) (1,375 ) Unamortized discount and premium, net (38 ) (39 ) Dominion Resources, Inc. total long-term debt $ 23,616 $ 21,805 (1) Represents weighted-average coupon rates for debt outstanding as of December 31, 2015. (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 were 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 Dominion’s Consolidated Balance Sheets. The option to redeem the notes expired in June 2015. At December 31, 2015, the notes are included in long-term debt in Dominion’s 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 for fair value hedge valuation in 2014. Excludes $100 million of variable rate short-term notes scheduled to mature in May 2016 that were purchased and cancelled using the proceeds from the February 2016 issuance of senior notes that mature in 2018.
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, 2015, were as follows: 2016 2017 2018 2019 2020 Thereafter Total (millions, except percentages) Dominion Gas $ 400 $ — $ — $ 450 $ 700 $ 1,750 $ 3,300 Weighted-average Coupon 1.05 % 2.50 % 2.80 % 4.15 % Virginia Power $ 476 $ 679 $ 850 $ 350 $ — $ 7,070 $ 9,425 Weighted-average Coupon 5.24 % 5.44 % 4.17 % 5.00 % — % 4.59 % Dominion Unsecured Senior Notes (1) $ 1,907 $ 1,354 $ 1,850 $ 2,000 $ 700 $ 13,230 $ 21,041 Tax-Exempt Financings 19 75 — — — 880 974 Unsecured Junior Subordinated Notes Payable to Affiliated Trusts — — — — — 10 10 Enhanced Junior Subordinated Notes — — — — — 1,348 1,348 Remarketable Subordinated Notes — — — 550 1,000 550 2,100 Total $ 1,926 $ 1,429 $ 1,850 $ 2,550 $ 1,700 $ 16,018 $ 25,473 Weighted-average Coupon 2.31 % 3.28 % 4.16 % 3.09 % 2.04 % 4.54 % (1) In February 2016, Dominion purchased and cancelled $100 million of variable rate short-term notes that would have otherwise matured in May 2016 using the proceeds from the February 2016 issuance of senior notes that mature in 2018. As a result, at December 31, 2015, $100 million of the notes were included in long-term debt 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) 6/7/2013 11 $ 533.5 $ 550.0 1.070 % 5.055 % $ 76.7 4/1/2016 4/1/2021 6/7/2013 11 $ 553.5 $ 550.0 1.180 % 4.820 % $ 79.3 7/1/2016 7/1/2019 7/1/2014 20 $ 982.0 $ 1,000.0 1.500 % 4.875 % $ 142.8 7/1/2017 7/1/2020 (1) Payments of $101 million and $66 million were made in 2015 and 2014, respectively. The stock purchase contract liability was $115 million and $216 million at December 31, 2015 and 2014, respectively.

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 2014 (millions) Dominion Net deferred losses on derivatives-hedging activities, net of tax of $110 and $116 $ (176 ) $ (178 ) Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(281) and $(333) 504 548 Net unrecognized pension and other postretirement benefit costs, net of tax of $525 and $530 (797 ) (782 ) Other comprehensive loss from equity method investees, net of tax of $4 and $3 (5 ) (4 ) Total AOCI $ (474 ) $ (416 ) Virginia Power Net deferred losses on derivatives-hedging activities, net of tax of $4 and $4 $ (7 ) $ (7 ) Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(30) and $(35) 47 57 Total AOCI $ 40 $ 50 Dominion Gas Net deferred losses on derivatives-hedging activities, net of tax of $10 and $11 $ (17 ) $ (20 ) Net unrecognized pension costs, net of tax of $56 and $46 (82 ) (66 ) Total AOCI $ (99 ) $ (86 )
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, 2015 Beginning balance $ (178 ) $ 548 $ (782 ) $ (4 ) $ (416 ) Other comprehensive income before reclassifications: gains (losses) 110 6 (66 ) (1 ) 49 Amounts reclassified from AOCI: (gains) losses (1) (108 ) (50 ) 51 — (107 ) Net current period other comprehensive income (loss) 2 (44 ) (15 ) (1 ) (58 ) Ending balance $ (176 ) $ 504 $ (797 ) $ (5 ) $ (474 ) 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 AOCI: (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 ) (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, 2015 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (203 ) Operating revenue 15 Purchased gas 1 Electric fuel and other energy-related purchases Interest rate contracts 11 Interest and related charges Total (176 ) Tax 68 Income tax expense Total, net of tax $ (108 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (110 ) Other income Impairment 31 Other income Total (79 ) Tax 29 Income tax expense Total, net of tax $ (50 ) Unrecognized pension and other postretirement benefit costs: Prior-service costs (credits) $ (12 ) Other operations and maintenance Actuarial losses 98 Other operations and maintenance Total 86 Tax (35 ) Income tax expense Total, net of tax $ 51 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
Summary of restricted stock activity	The following table provides a summary of restricted stock activity for the years ended December 31, 2015, 2014 and 2013: Shares Weighted - average Grant Date Fair Value (thousands) Nonvested at December 31, 2012 1,085 $ 44.46 Granted 312 54.70 Vested (356 ) 39.00 Cancelled and forfeited (34 ) 51.11 Nonvested at December 31, 2013 1,007 $ 49.35 Granted 354 67.98 Vested (278 ) 44.50 Cancelled and forfeited (18 ) 53.61 Nonvested at December 31, 2014 1,065 $ 56.74 Granted 302 73.26 Vested (510 ) 50.71 Cancelled and forfeited (2 ) 62.62 Nonvested at December 31, 2015 855 $ 66.16
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, 2015, 2014 and 2013: Targeted Number of Shares Weighted - average Grant Date Fair Value (thousands) Nonvested at December 31, 2012 4 $ 45.60 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 Granted 14 72.72 Vested (7 ) 56.22 Nonvested at December 31, 2015 24 $ 72.27
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, 2015 Beginning balance $ (7 ) $ 57 $ 50 Other comprehensive income before reclassifications: losses (1 ) (4 ) (5 ) Amounts reclassified from AOCI: (gains) losses (1) 1 (6 ) (5 ) Net current period other comprehensive income (loss) — (10 ) (10 ) Ending balance $ (7 ) $ 47 $ 40 Year Ended December 31, 2014 Beginning balance $ — $ 48 $ 48 Other comprehensive income before reclassifications: gains (losses) (4 ) 15 11 Amounts reclassified from AOCI: gains (1) (3 ) (6 ) (9 ) Net current period other comprehensive income (loss) (7 ) 9 2 Ending balance $ (7 ) $ 57 $ 50 (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, 2015 (Gains) losses on cash flow hedges: Commodity contracts $ 1 Electric fuel and other energy-related purchases Total 1 Tax — Income tax expense Total, net of tax $ 1 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (14 ) Other income Impairment 4 Other income Total (10 ) Tax 4 Income tax expense Total, net of tax $ (6 ) Year Ended December 31, 2014 (Gains) losses on cash flow hedges: Commodity contracts $ (5 ) Electric fuel and other energy-related purchases 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 )
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 costs Total (millions) Year Ended December 31, 2015 Beginning balance $ (20 ) $ (66 ) $ (86 ) Other comprehensive income before reclassifications: gains (losses) 6 (20 ) (14 ) Amounts reclassified from AOCI: (gains) losses (1) (3 ) 4 1 Net current period other comprehensive income (loss) 3 (16 ) (13 ) Ending balance $ (17 ) $ (82 ) $ (99 ) Year Ended December 31, 2014 Beginning balance $ 3 $ (61 ) $ (58 ) Other comprehensive income before reclassifications: losses (31 ) (10 ) (41 ) Amounts reclassified from AOCI losses (1) 8 5 13 Net current period other comprehensive loss (23 ) (5 ) (28 ) Ending balance $ (20 ) $ (66 ) $ (86 ) (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, 2015 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (6 ) Operating revenue Total (6 ) Tax 3 Income tax expense Total, net of tax $ (3 ) Unrecognized pension costs: Actuarial losses $ 7 Other operations and maintenance Total 7 Tax (3 ) Income tax expense Total, net of tax $ 4 Year Ended December 31, 2014 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (2 ) Operating revenue 14 Purchased gas Interest rate contracts 1 Interest and related charges Total 13 Tax (5 ) Income tax expense Total, net of tax $ 8 Unrecognized pension 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

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2015
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 Year Ended December 31, 2015 2014 2015 2014 (millions, except percentages) DOMINION Changes in benefit obligation: Benefit obligation at beginning of year $ 6,667 $ 5,625 $ 1,571 $ 1,360 Service cost 126 114 40 32 Interest cost 287 290 67 67 Benefits paid (246 ) (236 ) (79 ) (78 ) Actuarial (gains) losses during the year (443 ) 887 (138 ) 177 Plan amendments (1) — — (31 ) 9 Settlements and curtailments (2) — (13 ) — — Medicare Part D reimbursement — — — 4 Benefit obligation at end of year $ 6,391 $ 6,667 $ 1,430 $ 1,571 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 6,480 $ 6,113 $ 1,402 $ 1,315 Actual return (loss) on plan assets (71 ) 601 (1 ) 105 Employer contributions 3 15 12 12 Benefits paid (246 ) (236 ) (31 ) (30 ) Settlements (2) — (13 ) — — Fair value of plan assets at end of year $ 6,166 $ 6,480 $ 1,382 $ 1,402 Funded status at end of year $ (225 ) $ (187 ) $ (48 ) $ (169 ) Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 931 $ 946 $ 12 $ 10 Other current liabilities (14 ) (13 ) (3 ) (3 ) Noncurrent pension and other postretirement benefit liabilities (1,142 ) (1,120 ) (57 ) (176 ) Net amount recognized $ (225 ) $ (187 ) $ (48 ) $ (169 ) Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.96% - 4.99% 4.40 % 4.93% - 4.94% 4.40 % Weighted average rate of increase for compensation 4.22 % 4.22 % 4.22 % 4.22 % Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.50 % 8.50 % DOMINION GAS Changes in benefit obligation: Benefit obligation at beginning of year $ 638 $ 563 $ 320 $ 269 Service cost 15 12 7 6 Interest cost 27 28 14 13 Benefits paid (29 ) (29 ) (18 ) (16 ) Actuarial (gains) losses during the year (43 ) 64 (31 ) 38 Plan amendments — — — 9 Medicare Part D reimbursement — — — 1 Benefit obligation at end of year $ 608 $ 638 $ 292 $ 320 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 1,510 $ 1,403 $ 288 $ 273 Actual return (loss) on plan assets (14 ) 136 1 21 Employer contributions — — 12 10 Benefits paid (29 ) (29 ) (18 ) (16 ) Fair value of plan assets at end of year $ 1,467 $ 1,510 $ 283 $ 288 Funded status at end of year $ 859 $ 872 $ (9 ) $ (32 ) Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 859 $ 872 $ — $ — Noncurrent pension and other postretirement benefit liabilities (3) — — (9 ) (32 ) Net amount recognized $ 859 $ 872 $ (9 ) $ (32 ) Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.99 % 4.40 % 4.93 % 4.40 % 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 % 8.75 % 8.50 % 8.50 % (1) 2015 amount relates primarily to a plan amendment that changed retiree medical benefits for certain nonunion employees after Medicare eligibility. (2) Relates primarily to a settlement charge for certain executives. (3) 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, 2015 2014 2015 2014 (millions) DOMINION Benefit obligation $ 5,728 $ 5,970 $ 359 $ 1,564 Fair value of plan assets 4,571 4,838 299 1,385 DOMINION GAS Benefit obligation $ — $ — $ 292 $ 320 Fair value of plan assets — — 283 288
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, 2015 2014 (millions) Accumulated benefit obligation $ 5,198 $ 5,370 Fair value of plan assets 4,571 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 2016 $ 288 $ 92 2017 303 96 2018 324 99 2019 337 100 2020 359 102 2021-2025 2,023 512 DOMINION GAS 2016 $ 35 $ 18 2017 37 19 2018 39 21 2019 40 21 2020 41 21 2021-2025 208 107
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: At December 31, 2015 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) DOMINION Cash equivalents $ 16 $ — $ — $ 16 $ 13 $ 25 $ — $ 38 U.S. equity: Large Cap 1,178 — — 1,178 1,313 — — 1,313 Other 475 — — 475 530 — — 530 Non-U.S. equity: Large Cap 286 — — 286 234 — — 234 Other 493 — — 493 403 — — 403 Common/collective trust funds (1) — 330 — 330 — 360 — 360 Fixed income: Corporate debt instruments 40 672 — 712 45 666 — 711 U.S. Treasury securities and agency debentures 60 298 — 358 74 342 — 416 State and municipal 20 54 — 74 10 60 — 70 Other securities 9 61 — 70 6 80 — 86 Real estate-REITs 90 — — 90 40 — — 40 Total recorded at fair value $ 2,667 $ 1,415 $ — $ 4,082 $ 2,668 $ 1,533 $ — $ 4,201 Assets recorded at NAV (2) : Common/collective trust funds (1) 1,200 1,235 Real estate-Partnerships 153 209 Other alternative investments: Private equity 465 518 Debt 170 144 Hedge funds 86 162 Total recorded at NAV $ 2,074 $ 2,268 Total (3) $ 6,156 $ 6,469 DOMINION GAS Cash equivalents $ 4 $ — $ — $ 4 $ 3 $ 6 $ — $ 9 U.S. equity: Large Cap 280 — — 280 306 — — 306 Other 113 — — 113 124 — — 124 Non-U.S. equity: Large Cap 68 — — 68 54 — — 54 Other 117 — — 117 94 — — 94 Common/collective trust funds (4) — 78 — 78 — 84 — 84 Fixed income: Corporate debt instruments 9 160 — 169 11 155 — 166 U.S. Treasury securities and agency debentures 14 71 — 85 17 80 — 97 State and municipal 5 13 — 18 2 14 — 16 Other securities 2 14 — 16 1 19 — 20 Real estate-REITs: 22 — — 22 9 — — 9 Total recorded at fair value $ 634 $ 336 $ — $ 970 $ 621 $ 358 $ — $ 979 Assets recorded at NAV (2) : Common/collective trust funds (4) 286 288 Real estate-Partnerships 36 48 Other alternative investments: Private equity 111 121 Debt 40 34 Hedge funds 21 38 Total recorded at NAV $ 494 $ 529 Total (5) $ 1,464 $ 1,508 (1) Common/collective trust funds include $330 million and $360 million of John Hancock insurance contracts held at December 31, 2015 and 2014, 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) These investments that are measured at fair value using the NAV per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Consolidated Balance Sheets. (3) Includes net assets related to pending sales of securities of $112 million , net accrued income of $16 million , and excludes net assets related to pending purchases of securities of $118 million at December 31, 2015. 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. (4) Common/collective trust funds include $78 million and $84 million of John Hancock insurance contracts held at December 31, 2015 and 2014, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund. (5) Includes net assets related to pending sales of securities of $27 million , net accrued income of $4 million , and excludes net assets related to pending purchases of securities of $28 million at December 31, 2015. 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: At December 31, 2015 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) DOMINION Cash equivalents $ 1 $ 1 $ — $ 2 $ 1 $ 7 $ — $ 8 U.S. equity: Large Cap 468 — — 468 514 — — 514 Other 26 — — 26 28 — — 28 Non-U.S. equity: Large Cap 107 — — 107 102 — — 102 Other 27 — — 27 21 — — 21 Common/collective trust funds (1) — 18 — 18 — 19 — 19 Fixed income: Corporate debt instruments 2 37 — 39 3 35 — 38 U.S. Treasury securities and agency debentures 3 17 — 20 4 18 — 22 State and municipal 1 3 — 4 1 3 — 4 Other securities 1 3 — 4 — 4 — 4 Real estate-REITs 37 — — 37 2 — — 2 Total recorded at fair value $ 673 $ 79 $ — $ 752 $ 676 $ 86 $ — $ 762 Assets recorded at NAV (2) : Common/collective trust funds (1) 543 536 Real estate-Partnerships 14 19 Other alternative investments: Private equity 54 58 Debt 14 18 Hedge funds 5 9 Total recorded at NAV $ 630 $ 640 Total $ 1,382 $ 1,402 DOMINION GAS Cash equivalents $ — $ — $ — $ — $ — $ 2 $ — $ 2 U.S. equity-Large Cap 102 — — 102 113 — — 113 Non-U.S. equity-Large Cap 24 — — 24 26 — — 26 Real estate-REITs 11 — — 11 — — — — Total recorded at fair value $ 137 $ — $ — $ 137 $ 139 $ 2 $ — $ 141 Assets recorded at NAV (2) : Common/collective trust funds (3) 132 129 Real estate-Partnerships 2 2 Other alternative investments: Private equity 11 12 Debt 1 4 Total recorded at NAV $ 146 $ 147 Total $ 283 $ 288 (1) Common/collective trust funds include $18 million and $19 million of John Hancock insurance contracts held at December 31, 2015 and 2014, 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) These investments that are measured at fair value using the NAV per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Consolidated Balance Sheets. (3) See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
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, 2015 2014 2013 2015 2014 2013 (millions, except percentages) DOMINION Service cost $ 126 $ 114 $ 131 $ 40 $ 32 $ 43 Interest cost 287 290 271 67 67 73 Expected return on plan assets (531 ) (499 ) (462 ) (117 ) (111 ) (92 ) Amortization of prior service (credit) cost 2 3 3 (27 ) (28 ) (15 ) Amortization of net actuarial loss 160 111 165 6 2 7 Settlements and curtailments (1) — 1 (2 ) — — (15 ) Special termination benefits — — — — — 1 Net periodic benefit (credit) cost $ 44 $ 20 $ 106 $ (31 ) $ (38 ) $ 2 Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ 159 $ 784 $ (968 ) $ (18 ) $ 183 $ (255 ) Prior service (credit) cost — — 1 (31 ) 9 (215 ) Settlements and curtailments (1) — (1 ) (22 ) — — (7 ) Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (160 ) (111 ) (165 ) (6 ) (2 ) (7 ) Amortization of prior service credit (cost) (2 ) (3 ) (3 ) 27 28 15 Total recognized in other comprehensive income and regulatory assets and liabilities $ (3 ) $ 669 $ (1,157 ) $ (28 ) $ 218 $ (469 ) Significant assumptions used to determine periodic cost: Discount rate 4.40 % 5.20% - 5.30% 4.40% - 4.80% 4.40 % 4.20% - 5.10% 4.40% - 4.80% Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.50 % 8.50 % 8.50 % 7.75 % Weighted average rate of increase for compensation 4.22 % 4.21 % 4.21 % 4.22 % 4.22 % 4.22 % Healthcare cost trend rate (2) 7.00 % 7.00 % 7.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (2) 5.00 % 5.00 % 4.60 % Year that the rate reaches the ultimate trend rate (2)(3) 2019 2018 2062 DOMINION GAS Service cost $ 15 $ 12 $ 13 $ 7 $ 6 $ 7 Interest cost 27 28 27 14 13 12 Expected return on plan assets (126 ) (115 ) (106 ) (24 ) (23 ) (19 ) Amortization of prior service (credit) cost 1 1 1 (1 ) (1 ) (3 ) Amortization of net actuarial loss 20 19 26 2 — 2 Net periodic benefit (credit) cost $ (63 ) $ (55 ) $ (39 ) $ (2 ) $ (5 ) $ (1 ) Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ 97 $ 43 $ (127 ) $ (9 ) $ 40 $ (40 ) Prior service cost — — — — 10 — Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (20 ) (19 ) (26 ) (2 ) — (2 ) Amortization of prior service credit (cost) (1 ) (1 ) (1 ) 1 1 3 Total recognized in other comprehensive income and regulatory assets and liabilities $ 76 $ 23 $ (154 ) $ (10 ) $ 51 $ (39 ) Significant assumptions used to determine periodic cost: Discount rate 4.40 % 5.20 % 4.40% - 4.80% 4.40 % 4.20% - 5.00% 4.40% - 4.70% Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.50 % 8.50 % 8.50 % 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) 7.00 % 7.00 % 7.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (2) 5.00 % 5.00 % 4.60 % Year that the rate reaches the ultimate trend rate (2)(3) 2019 2018 2062 (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, 2015 2014 2015 2014 (millions) DOMINION Net actuarial loss $ 2,381 $ 2,382 $ 114 $ 139 Prior service (credit) cost 5 7 (237 ) (233 ) Total (1) $ 2,386 $ 2,389 $ (123 ) $ (94 ) DOMINION GAS Net actuarial loss $ 380 $ 303 $ 33 $ 43 Prior service (credit) cost 1 1 7 7 Total (2) $ 381 $ 304 $ 40 $ 50 (1) As of December 31, 2015, of the $2.4 billion and $(123) million related to pension benefits and other postretirement benefits, $1.4 billion and $(90) million , respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. 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. (2) As of December 31, 2015, of the $381 million related to pension benefits, $138 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $40 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. 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.
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, 2015 that are expected to be amortized as components of net periodic benefit (credit) cost in 2016: Pension Benefits Other Postretirement Benefits (millions) DOMINION Net actuarial loss $ 111 $ 5 Prior service (credit) cost 1 (28 ) DOMINION GAS Net actuarial loss $ 13 $ 1 Prior service (credit) 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 2016 $ 21 $ (13 ) Effect on other postretirement benefit obligation at December 31, 2015 157 (129 ) DOMINION GAS Effect on net periodic cost for 2016 $ 5 $ (3 ) Effect on other postretirement benefit obligation at December 31, 2015 34 (26 )

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
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 $ 1.70 Kewaunee 1.06 Virginia Power (1) Surry $ 1.70 North Anna 1.70 (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, 2015 are as follows: 2016 2017 2018 2019 2020 Thereafter Total (millions) Dominion $ 67 $ 62 $ 54 $ 43 $ 25 $ 153 $ 404 Virginia Power $ 30 $ 27 $ 23 $ 17 $ 14 $ 27 $ 138 Dominion Gas $ 26 $ 25 $ 23 $ 18 $ 6 $ 19 $ 117
Subsidiary guarantees	At December 31, 2015, Dominion had issued the following subsidiary guarantees: Stated Limit Value (1) (millions) Subsidiary debt (2) $ 27 $ 27 Commodity transactions (3) 2,371 932 Nuclear obligations (4) 184 75 Cove Point (5) 1,910 — Solar (6) 1,555 647 Other (7) 515 31 Total $ 6,562 $ 1,712 (1) Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2015 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 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, 2015, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $55 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, 2015, 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: 2016 2017 2018 2019 2020 Thereafter Total (millions) Purchased electric capacity (1) $ 249 $ 157 $ 104 $ 65 $ 52 $ 46 $ 673 (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, 2015, the present value of Virginia Power's total commitment for capacity payments is $577 million . Capacity payments totaled $305 million , $330 million , and $345 million , and energy payments totaled $198 million , $304 million , and $236 million for the years ended 2015, 2014 and 2013, respectively.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 2014 2013 (millions) Commodity purchases from affiliates $ 555 $ 543 $ 417 Services provided by affiliates (1) 422 432 415 Services provided to affiliates 22 22 21 (1) Includes capitalized expenditures.
Dominion Gas Holdings, LLC
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to related parties, including technical services. The costs of these services follow: Year Ended December 31, 2015 2014 2013 (millions) Purchases of natural gas and transportation and storage services from affiliates $ 10 $ 34 $ 31 Sales of natural gas and transportation and storage services to affiliates 69 84 109 Services provided by related parties (1) 133 106 116 Services provided to related parties (2) 101 17 4 (1) Includes capitalized expenditures. (2) Amounts primarily attributable to Atlantic Coast Pipeline. The following table presents affiliated and related party activity reflected in Dominion Gas' Consolidated Balance Sheets: At December 31, 2015 2014 (millions) Other receivables (1) $ 7 $ 17 Customer receivables from related parties 4 5 Imbalances receivable from affiliates (2) 1 3 Affiliated notes receivable (3) 14 9 (1) Represents amounts due from Atlantic Coast Pipeline, a related party VIE. (2) Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets. (3) 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, 2015
Segment Reporting Information [Line Items]
Segment Reporting Disclosure Other Information	A description of the operations included in the Companies' primary operating segments is as follows: Primary Operating Segment Description of Operations Dominion Virginia Power Dominion Gas DVP Regulated electric distribution X X Regulated electric transmission X X Dominion Generation Regulated electric fleet X X Merchant electric fleet X Dominion Energy Gas transmission and storage X (1) X Gas distribution and storage X X Gas gathering and processing X X LNG import and storage X Nonregulated retail energy marketing (2) X (1) Includes remaining producer services activities. (2) As a result of Dominion's decision to realign its business units effective for 2015 year-end reporting, nonregulated retail energy marketing operations were moved from the Dominion Generation segment to the Dominion Energy segment.
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion's operations: Year Ended December 31, DVP Dominion Generation (1) Dominion Energy (1) Corporate and Other Adjustments & Eliminations (1) Consolidated Total (millions) 2015 Total revenue from external customers $ 2,091 $ 7,001 $ 1,877 $ (27 ) $ 741 $ 11,683 Intersegment revenue 20 15 695 554 (1,284 ) — Total operating revenue 2,111 7,016 2,572 527 (543 ) 11,683 Depreciation, depletion and amortization 498 591 262 44 — 1,395 Equity in earnings of equity method investees — (15 ) 60 11 — 56 Interest income — 64 25 13 (44 ) 58 Interest and related charges 230 262 27 429 (44 ) 904 Income taxes 307 465 423 (290 ) — 905 Net income (loss) attributable to Dominion 490 1,120 680 (391 ) — 1,899 Investment in equity method investees — 245 1,042 33 — 1,320 Capital expenditures 1,607 2,190 2,153 43 — 5,993 Total assets (billions) 14.7 25.6 15.3 9.0 (5.8 ) 58.8 2014 Total revenue from external customers $ 1,918 $ 7,135 $ 2,446 $ (12 ) $ 949 $ 12,436 Intersegment revenue 18 34 880 572 (1,504 ) — Total operating revenue 1,936 7,169 3,326 560 (555 ) 12,436 Depreciation, depletion and amortization 462 514 243 73 — 1,292 Equity in earnings of equity method investees — (18 ) 54 10 — 46 Interest income — 58 23 20 (33 ) 68 Interest and related charges 205 240 11 770 (33 ) 1,193 Income taxes 317 365 463 (693 ) — 452 Net income (loss) attributable to Dominion 502 1,061 717 (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) 13.0 23.9 13.0 8.7 (4.3 ) 54.3 2013 Total revenue from external customers $ 1,825 $ 6,664 $ 3,566 $ 3 $ 1,062 $ 13,120 Intersegment revenue 9 283 739 609 (1,640 ) — Total operating revenue 1,834 6,947 4,305 612 (578 ) 13,120 Depreciation, depletion and amortization 427 511 235 35 — 1,208 Equity in earnings of equity method investees — (14 ) 21 7 — 14 Interest income — 59 19 42 (66 ) 54 Interest and related charges 175 220 26 522 (66 ) 877 Income taxes 287 436 456 (287 ) — 892 Loss from discontinued operations, net of tax — — — (92 ) — (92 ) Net income (loss) attributable to Dominion 475 963 711 (452 ) — 1,697 Capital expenditures 1,361 1,605 1,043 95 — 4,104 (1) Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.
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 Generation Corporate and Other Adjustments & Eliminations Consolidated Total (millions) 2015 Operating revenue $ 2,099 $ 5,566 $ (43 ) $ — $ 7,622 Depreciation and amortization 498 453 2 — 953 Interest income — 7 — — 7 Interest and related charges 230 210 4 (1 ) 443 Income taxes 308 437 (86 ) 659 Net income (loss) 490 750 (153 ) — 1,087 Capital expenditures 1,569 1,120 — — 2,689 Total assets (billions) 14.7 17.0 — (0.1 ) 31.6 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
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 Other Consolidated Total (millions) 2015 Operating revenue $ 1,716 $ — $ 1,716 Depreciation and amortization 213 4 217 Equity in earnings of equity method investees 23 — 23 Interest income 1 — 1 Interest and related charges 72 1 73 Income taxes 296 (13 ) 283 Net income (loss) 478 (21 ) 457 Investment in equity method investees 102 — 102 Capital expenditures 795 — 795 Total assets (billions) 9.7 0.6 10.3 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 Capital expenditures 650 — 650

Quarterly Financial and Commo57

Quarterly Financial and Common Stock Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Quarterly Financial and Common Stock Data	First Quarter Second Quarter Third Quarter Fourth Quarter Year (millions, except per share amounts) 2015 Operating revenue $ 3,409 $ 2,747 $ 2,971 $ 2,556 $ 11,683 Income from operations 1,002 773 1,123 638 3,536 Net income including noncontrolling interests 540 418 599 366 1,923 Income from continuing operations (1) 536 413 593 357 1,899 Net income attributable to Dominion 536 413 593 357 1,899 Basic EPS: Income from continuing operations (1) 0.91 0.70 1.00 0.60 3.21 Net income attributable to Dominion 0.91 0.70 1.00 0.60 3.21 Diluted EPS: Income from continuing operations (1) 0.91 0.70 1.00 0.60 3.20 Net income attributable to Dominion 0.91 0.70 1.00 0.60 3.20 Dividends declared per share 0.6475 0.6475 0.6475 0.6475 2.5900 Common stock prices (intraday high-low) $79.89 - 68.25 $74.34 - 66.52 $76.59 - 66.65 $74.88 - 64.54 $79.89 - 64.54 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 0.90 0.42 2.24 Net income attributable to Dominion 0.65 0.27 0.90 0.42 2.24 Dividends declared per share 0.60 0.60 0.60 0.60 2.40 Common stock prices (intraday high-low) $72.22 - $73.75 - $71.62 - 64.71 $80.89 - $80.89 - (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 Quarter Second Quarter Third Quarter Fourth Quarter Year (millions) 2015 Operating revenue $ 2,137 $ 1,813 $ 2,058 $ 1,614 $ 7,622 Income from operations 525 481 741 374 2,121 Net income 269 246 385 187 1,087 Balance available for common stock 269 246 385 187 1,087 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
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 Quarter Second Quarter Third Quarter Fourth Quarter Year (millions) 2015 Operating revenue $ 531 $ 395 $ 365 $ 425 $ 1,716 Income from operations 271 153 202 163 789 Net income 161 85 111 100 457 2014 Operating revenue $ 569 $ 428 $ 391 $ 510 $ 1,898 Income from operations 265 154 177 255 851 Net income 164 93 107 148 512

Nature of Operations (Narrative

Nature of Operations (Narrative) (Details) $ / shares in Units, $ in Millions	Dec. 31, 2015	Sep. 30, 2015shares	Oct. 31, 2014USD ($)shares	Dec. 31, 2015Segment	Oct. 20, 2014$ / shares
Subsidiary, Sale of Stock [Line Items]
Number of operating segments | Segment				3
Dominion Midstream Partners, LP
Subsidiary, Sale of Stock [Line Items]
Percentage of limited partner interests in Dominion Midstream Partners, LP	64.10%
Dominion Midstream Partners, LP | Iroquois | Partnership Interest
Subsidiary, Sale of Stock [Line Items]
Common units included in initial public offering | shares		8,600,000
Noncontrolling partnership interest	25.93%			25.93%
Dominion Midstream Partners, LP | IPO
Subsidiary, Sale of Stock [Line Items]
Common units included in initial public offering | shares			20,125,000
Price per unit for units included in initial public offering | $ / shares					$ 21
Net proceeds received from sale of units | $			$ 392
Dominion Midstream Partners, LP | Over-Allotment Option
Subsidiary, Sale of Stock [Line Items]
Common units included in initial public offering | shares			2,625,000
Virginia Electric and Power Company
Subsidiary, Sale of Stock [Line Items]
Number of operating segments | Segment				2
Dominion Gas Holdings, LLC
Subsidiary, Sale of Stock [Line Items]
Number of operating segments | Segment				1

Significant Accounting Polici59

Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2015
Accounting Policy [Line Items]
Capitalized Interest Costs, Including Allowance for Funds Used During Construction		$ 100	$ 80	$ 66
Accrued unbilled revenue		$ 462	564
Percentage of fuel currently subject to deferred fuel accounting		84.00%
Accounts payable for checks outstanding		$ 27	42
Margin deposit assets		16	287
Margin liabilities			34
Virginia Electric and Power Company
Accounting Policy [Line Items]
Accrued unbilled revenue		333	407
Income tax receivable			225
Noncurrent income tax payable			38
Accounts payable for checks outstanding		11	20
Margin deposit assets			6
Capitalized interest costs		30	39	33
AFUDC related to projects		19	8	32
Dominion Gas Holdings, LLC
Accounting Policy [Line Items]
Accrued unbilled revenue		98	127
Income tax receivable			96
Accounts payable for checks outstanding		7	9
Capitalized interest costs		1	1	$ 5
Inventory under LIFO method		24	12
Amount exceeded on LIFO basis		109	98
Federal | IRS | Virginia Electric and Power Company
Accounting Policy [Line Items]
Income taxes payable		9
Federal | IRS | Tax Year 2014 | Virginia Electric and Power Company
Accounting Policy [Line Items]
Refund received for 2014 federal income tax payments	$ 229
Federal | IRS | Tax Year 2014 | Dominion Gas Holdings, LLC
Accounting Policy [Line Items]
Refund received for 2014 federal income tax payments	$ 93
State | Virginia Electric and Power Company
Accounting Policy [Line Items]
Income taxes payable		1
Income tax receivable		10
Noncurrent income taxes receivable		14	13
Noncurrent income tax payable		2
State | Dominion Gas Holdings, LLC
Accounting Policy [Line Items]
Income taxes payable		1	14
Income tax receivable		4
Noncurrent income taxes receivable			20
Noncurrent income tax payable		22	$ 7
Affiliated Entity | Virginia Electric and Power Company
Accounting Policy [Line Items]
Affiliated receivable for federal income tax payments expected to be refunded		296
Affiliated Entity | Dominion Gas Holdings, LLC
Accounting Policy [Line Items]
Affiliated receivable for federal income tax payments expected to be refunded		$ 91
Merchant Solar Projects | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Accounting Policy [Line Items]
SunEdison's ownership interest in merchant solar projects		33.00%			33.00%

Significant Accounting Polici60

Significant Accounting Policies (Depreciation Rates and Estimated Useful Life) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	2.78%	2.66%	2.71%
Generation | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.78%	2.66%	2.71%
Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.42%	2.38%	2.36%
Transmission | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.33%	2.34%	2.28%
Transmission | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.46%	2.40%	2.43%
Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.11%	3.12%	3.13%
Distribution | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.33%	3.34%	3.33%
Distribution | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.45%	2.47%	2.50%
Storage
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.42%	2.39%	2.43%
Storage | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	2.44%	2.40%	2.43%
Gas gathering and processing
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.19%	2.81%	2.39%
Gas gathering and processing | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.20%	2.82%	2.39%
General and other
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.67%	3.62%	3.82%
General and other | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	3.40%	3.29%	3.51%
General and other | Dominion Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation rates	4.72%	5.77%	5.93%
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 Dispositions61

Acquisitions and Dispositions (Narrative) (Details)		Jan. 31, 2016USD ($)$ / shares	Apr. 01, 2015USD ($)$ / sharesshares	Dec. 31, 2015USD ($)ProjectMW	Sep. 30, 2015USD ($)ProjectmiMWshares	Jun. 30, 2015USD ($)ProjectMW	Jan. 31, 2015USD ($)mi	Mar. 31, 2014USD ($)	Aug. 31, 2013USD ($)	Jun. 30, 2013USD ($)	Dec. 31, 2015USD ($)	Jun. 30, 2013USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Remaining ownership interest percentage				100.00%							100.00%		100.00%
Required payments				$ 50,000,000							$ 50,000,000		$ 50,000,000
Contributions from SunEdison to Four Brothers and Three Cedars													103,000,000
Goodwill	[1]			$ 3,294,000,000							$ 3,294,000,000		3,294,000,000	$ 3,044,000,000	$ 3,086,000,000
Proceeds from sale of electric retail energy marketing business													$ 0	187,000,000	0
Asset disposition adjustment														42,000,000
Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage	[2]			50.65%							50.65%		50.65%
Elwood
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage									50.00%
Discontinued Operations, Disposed of by Sale | Elwood
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of equity method investment									$ 465,000,000
Discontinued Operations, Disposed of by Sale | Other Income | Elwood
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of investment									35,000,000
After tax gain on sale of investment									$ 25,000,000
Merchant Solar Projects | SunEdison | Call Option
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Remaining ownership interest percentage				67.00%							67.00%		67.00%
Merchant Solar Projects | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
SunEdison's ownership interest in merchant solar projects				33.00%	33.00%						33.00%		33.00%
Number of currently wholly-owned merchant solar projects | Project					24
MW Capacity | MW					425
Sales price of equity interest to noncontrolling interest owners					$ 300,000,000
Number of solar projects sold under agreement | Project				15
Sales price				$ 184,000,000							$ 184,000,000		$ 184,000,000
Electric Retail Energy Marketing Business | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of electric retail energy marketing business								$ 187,000,000
Gain on sale								100,000,000
After-tax gain on sale								57,000,000
Asset disposition adjustment								$ 31,000,000
Illinois Gas Contracts | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sales price										$ 32,000,000		$ 32,000,000
Gain on sale										29,000,000
After-tax gain on sale										18,000,000
Asset disposition adjustment										$ 3,000,000
Brayton Point and Kincaid | Discontinued Operations, Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment charge												48,000,000
Long-lived assets impairment charges, net of tax												$ 28,000,000
Brayton Point and Kincaid | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Loss from discontinued operation															17,000,000
Loss on discontinued operation, net of tax															18,000,000
Brayton Point and Kincaid | Discontinued Operations, Disposed of by Sale | Loss from Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Asset disposition adjustment															16,000,000
Partnership Interest | National Grid | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest percentage					20.40%
Partnership Interest | NJNR Pipeline Company | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest percentage					5.53%
Four Brothers Solar, LLC and Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Remaining ownership interest percentage				50.00%							50.00%		50.00%
Four Brothers Solar, LLC and Three Cedars | Investment Credits | Federal
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of expected federal investment tax credits on projects to be claimed				99.00%							99.00%		99.00%
Four Brothers Solar, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Purchase price						$ 64,000,000
Acquisition price payable						$ 62,000,000
MW Capacity | MW						320
Percentage of equity interests acquired						50.00%
Acquisition price in cash						$ 2,000,000
Number of Projects | Project						4
Estimated project cost once constructed				$ 730,000,000							$ 730,000,000		$ 730,000,000
Purchase price						$ 64,000,000
Net property plant and equipment acquired						89,000,000
Amount of noncontrolling interest						25,000,000
Four Brothers Solar, LLC | Obligation to Contribute Capital to Fund Construction of Projects | Limited Liability Company
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Required payments						$ 445,000,000
Amount of contributions				138,000,000							138,000,000		138,000,000
Four Brothers Solar, LLC | Current Liabilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payable included in other current liabilities				43,000,000							43,000,000		43,000,000
Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Purchase price					$ 43,000,000
Acquisition price payable					$ 37,000,000
MW Capacity | MW					210
Percentage of equity interests acquired					50.00%
Acquisition price in cash					$ 6,000,000
Number of Projects | Project					3
Estimated project cost once constructed				425,000,000							425,000,000		425,000,000
Purchase price					$ 43,000,000
Net property plant and equipment acquired					65,000,000
Amount of noncontrolling interest					22,000,000
Three Cedars | Obligation to Contribute Capital to Fund Construction of Projects | Affiliated Entity
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Required payments					$ 276,000,000
Amount of contributions				60,000,000							60,000,000		60,000,000
Three Cedars | Current Liabilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payable included in other current liabilities				$ 29,000,000							29,000,000		$ 29,000,000
DCG
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Purchase price							$ 497,000,000
Percentage of equity interests acquired							100.00%
Net property plant and equipment acquired							$ 277,000,000
Length of FERC regulated interstate natural gas pipeline | mi							1,500
Goodwill							$ 250,000,000
Amount expected to be deductible for tax purposes							225,000,000
Amount of regulatory liabilities							$ 38,000,000
SunEdison | Four Brothers Solar, LLC and Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions from SunEdison to Four Brothers and Three Cedars											$ 103,000,000
Dominion Midstream Partners, LP | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage	[2]			25.93%							25.93%		25.93%
Dominion Midstream Partners, LP | Partnership Interest | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
SunEdison's ownership interest in merchant solar projects				25.93%							25.93%		25.93%
Ownership percentage					25.93%
Length of FERC regulated interstate natural gas pipeline | mi					416
Number of common units issued | shares					8,600,000
Value of common units at closing					$ 216,000,000
Dominion Midstream Partners, LP | Partnership Interest | National Grid | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of common units issued | shares					6,800,000
Dominion Midstream Partners, LP | Partnership Interest | NJNR Pipeline Company | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of common units issued | shares					1,800,000
Dominion Midstream Partners, LP | Affiliated Entity | DCG | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sales price			$ 501,000,000
Ownership interest percentage			100.00%
Dominion Midstream Partners, LP | Affiliated Entity | DCG | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Unsecured Promissory Note Receivable | Notes Receivable
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Term of senior unsecured promissory note payable			2 years
Senior unsecured promissory note payable by Dominion Midstream			$ 301,000,000
Interest rate (percentage)			0.60%
Dominion Midstream Partners, LP | Affiliated Entity | Partnership Interest | DCG | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of common units issued | shares			5,112,139
Value of common units at closing			$ 200,000,000
Number of trading days			10 days
Price per unit | $ / shares			$ 39.12
Dominion Gas Holdings, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Goodwill	[1]			$ 542,000,000							$ 542,000,000		$ 542,000,000	542,000,000	$ 545,000,000
Asset disposition adjustment														$ 3,000,000
Dominion Gas Holdings, LLC | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage	[2]			24.72%							24.72%		24.72%
Dominion Gas Holdings, LLC | Partnership Interest | Iroquois
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage				24.72%							24.72%		24.72%
Virginia Electric and Power Company | Morgans Corner Solar Energy, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Purchase price				$ 47,000,000
MW Capacity | MW				20
Percentage of equity interests acquired				100.00%							100.00%		100.00%
Virginia Electric and Power Company | Morgans Corner Solar Energy, LLC | Solar Development Project
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total cost of project placed into service				$ 49,000,000							$ 49,000,000		$ 49,000,000
Virginia Electric and Power Company | Morgans Corner Solar Energy, LLC | Supply Agreement with US Navy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Duration of supply agreement				10 years
Subsequent Event | Questar Corporation
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Price per unit | $ / shares		$ 25
Purchase price		$ 4,400,000,000
Debt outstanding		1,600,000,000
Acquisition price payable		3,900,000,000
Required termination fee to Questar per agreement		154,000,000
Required termination fee to Dominion per agreement		$ 99,000,000
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	Comprised of Dominion Midstream's interest of 25.93% and Dominion Gas' interest of 24.72%. See Note 15 for more information.

Acquisitions and Dispositions62

Acquisitions and Dispositions (Schedule of Acquisitions of Solar Projects) (Details) $ in Millions

1 Months Ended

3 Months Ended

Oct. 31, 2016USD ($)

Dec. 31, 2015USD ($)

Nov. 30, 2015USD ($)ProjectMW

Aug. 31, 2015USD ($)

Jul. 31, 2015USD ($)ProjectMW

Jun. 30, 2015USD ($)ProjectMW

May. 31, 2015USD ($)

Apr. 30, 2015USD ($)ProjectMW

Jan. 31, 2015USD ($)

Dec. 31, 2014USD ($)ProjectMW

Nov. 30, 2014USD ($)ProjectMW

Mar. 31, 2014USD ($)ProjectMW

Dec. 31, 2014USD ($)

Recurrent Energy Development Holdings, LLC

Business Acquisition [Line Items]

Number of Projects | Project

6

Initial Acquisition Cost (millions)

[1]

$ 50

Project Cost (millions)

[2]

$ 428

MW Capacity | MW

139

CSI Project Holdco, LLC

Business Acquisition [Line Items]

Number of Projects | Project

1

Initial Acquisition Cost (millions)

[1]

$ 79

Project Cost (millions)

[2]

$ 79

MW Capacity | MW

20

EDF Renewable Development, Inc.

Business Acquisition [Line Items]

Number of Projects | Project

1

3

[3]

1

Initial Acquisition Cost (millions)

[1]

$ 68

$ 106

[3]

$ 71

Project Cost (millions)

[2]

$ 68

$ 106

[3]

$ 71

MW Capacity | MW

18

24

[3]

20

EC&R NA Solar PV, LLC

Business Acquisition [Line Items]

Number of Projects | Project

1

1

Initial Acquisition Cost (millions)

[1]

$ 65

$ 66

Project Cost (millions)

[2]

$ 65

$ 66

MW Capacity | MW

20

20

SunPeak Solar, LLC

Business Acquisition [Line Items]

Number of Projects | Project

1

Initial Acquisition Cost (millions)

[1]

$ 42

Project Cost (millions)

[2]

$ 71

MW Capacity | MW

20

Community Energy, Inc.

Business Acquisition [Line Items]

Number of Projects | Project

1

Initial Acquisition Cost (millions)

[1]

$ 34

MW Capacity | MW

80

Community Energy, Inc. | Scenario, Forecast

Business Acquisition [Line Items]

Project Cost (millions)

[2]

$ 212

[1]

The purchase price was primarily allocated to Property, Plant and Equipment.

[2]

Includes acquisition cost.

[3]

One of the projects, Marin Carport, is expected to begin commercial operations in 2016.

Acquisitions and Dispositions63

Acquisitions and Dispositions (Schedule of Disposal Groups, Including Discontinued Operations, Income Statement) (Details) - Discontinued Operations, Held-for-sale or Disposed of by Sale - Brayton Point and Kincaid $ in Millions	12 Months Ended
	Dec. 31, 2013USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating revenue	$ 304
Loss before income taxes	(135)	[1]
Charges related to early redemption of debt	$ 64
[1]	Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013.

Operating Revenue (Operating Re

Operating Revenue (Operating Revenue) (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Electric sales:
Regulated									$ 7,482		$ 7,460		$ 7,193
Nonregulated									1,488		1,839		2,511
Gas sales:
Regulated									218		334		323
Nonregulated									471		751		930
Gas transportation and storage									1,616		1,543		1,535
Other									408		509		628
Total operating revenue	$ 2,556	$ 2,971	$ 2,747	$ 3,409	$ 2,943	$ 3,050	$ 2,813	$ 3,630	11,683		12,436		13,120
Virginia Electric and Power Company
Electric sales:
Regulated									7,482		7,460		7,193
Gas sales:
Other									140		119		102
Total operating revenue	1,614	2,058	1,813	2,137	1,814	2,053	1,729	1,983	7,622	[1]	7,579	[1]	7,295	[1]
Dominion Gas Holdings, LLC
Gas sales:
Regulated									122		209		202
Nonregulated									10		26		32
Gas transportation and storage									1,366		1,353		1,338
NGL revenue									93		212		292
Other									125		98		73
Total operating revenue	$ 425	$ 365	$ 395	$ 531	$ 510	$ 391	$ 428	$ 569	$ 1,716	[2]	$ 1,898	[2]	$ 1,937	[2]
[1]	See Note 24 for amounts attributable to affiliates.
[2]	See Note 24 for amounts attributable to related parties.

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Loss Carryforwards [Line Items]
Investment tax credits		$ (134)	$ (152)	$ (48)
Unrecognized tax benefits that would impact effective tax rate		69	77	126
Increase (decrease) in unrecognized tax benefits		(6)	(47)	(29)
Scenario, Forecast
Operating Loss Carryforwards [Line Items]
Decrease in Unrecognized tax benefits due to settlement negotiations and expiration of statutes of limitations	$ 30
Amount that earnings could potentially increase if changes were to occur	15
Federal | IRS
Operating Loss Carryforwards [Line Items]
Benefit related to carryback recognized		20
Operating loss carryforward		594
Investment tax credits		407
Tax credits		89
Payment after conclusion of audit				46
State
Operating Loss Carryforwards [Line Items]
Operating loss carryforward		1,600
Carryforwards valuation allowance		1,100
General Business | State
Operating Loss Carryforwards [Line Items]
Tax credits		145
Investment Credits | State
Operating Loss Carryforwards [Line Items]
Tax credits		40
Virginia Electric and Power Company
Operating Loss Carryforwards [Line Items]
Investment tax credits		(11)	0	0
Unrecognized tax benefits that would impact effective tax rate		8	8	8
Increase (decrease) in unrecognized tax benefits		1	1	4
Virginia Electric and Power Company | Federal | IRS
Operating Loss Carryforwards [Line Items]
Operating loss carryforward		7
Tax credits		38
Virginia Electric and Power Company | Investment Credits | State
Operating Loss Carryforwards [Line Items]
Amount of tax credits		9
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	19	19
Increase (decrease) in unrecognized tax benefits		1	$ 1	$ 1
Dominion Gas Holdings, LLC | Scenario, Forecast
Operating Loss Carryforwards [Line Items]
Decrease in Unrecognized tax benefits due to settlement negotiations and expiration of statutes of limitations	22
Amount that earnings could potentially increase if changes were to occur	$ 10
Dominion Gas Holdings, LLC | Federal | IRS
Operating Loss Carryforwards [Line Items]
Operating loss carryforward		$ 10

Income Taxes (Income Tax Expens

Income Taxes (Income Tax Expense for Continuing Operations Including Noncontrolling Interests) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current:
Federal	$ (24)	$ (11)	$ 317
State	75	14	110
Total current expense	51	3	427
Federal
Taxes before operating loss carryforwards and investment tax credits	384	956	563
Tax utilization (benefit) of operating loss carryforwards	539	(352)	(18)
Investment tax credits	(134)	(152)	(48)
State	66	(2)	(31)
Total deferred expense	855	450	466
Amortization of deferred investment tax credits	(1)	(1)	(1)
Total income tax expense	905	452	892
Virginia Electric and Power Company
Current:
Federal	316	85	357
State	92	67	62
Total current expense	408	152	419
Federal
Taxes before operating loss carryforwards and investment tax credits	154	381	224
Tax utilization (benefit) of operating loss carryforwards	96	0	0
Investment tax credits	(11)	0	0
State	13	16	17
Total deferred expense	252	397	241
Amortization of deferred investment tax credits	(1)	(1)	(1)
Total income tax expense	659	548	659
Dominion Gas Holdings, LLC
Current:
Federal	90	86	158
State	30	32	41
Total current expense	120	118	199
Federal
Taxes before operating loss carryforwards and investment tax credits	156	192	92
Tax utilization (benefit) of operating loss carryforwards	6	0	0
Investment tax credits	0	0	0
State	1	24	10
Total deferred expense	163	216	102
Amortization of deferred investment tax credits	0	0	0
Total income tax expense	$ 283	$ 334	$ 301

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, 2015	Dec. 31, 2014	Dec. 31, 2013
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	3.70%	0.00%	2.10%
Investment tax credits	(4.70%)	(8.60%)	(1.80%)
Production tax credits	(0.80%)	(1.20%)	(0.60%)
Valuation allowances	(0.30%)	0.70%	(0.10%)
AFUDC - equity	(0.30%)	0.00%	(0.60%)
Employee stock ownership plan deduction	(0.60%)	(0.90%)	(0.60%)
Other, net	0.00%	0.40%	(0.40%)
Effective tax rate	32.00%	25.40%	33.00%
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	3.90%	3.80%	3.10%
Investment tax credits	(0.60%)	(0.00%)	(0.00%)
Production tax credits	(0.60%)	(0.60%)	(0.20%)
Valuation allowances	0.00%	0.00%	0.00%
AFUDC - equity	(0.60%)	0.00%	(0.80%)
Employee stock ownership plan deduction	(0.00%)	(0.00%)	(0.00%)
Other, net	0.60%	0.80%	(0.40%)
Effective tax rate	37.70%	39.00%	36.70%
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	2.70%	4.40%	4.30%
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	0.20%	0.00%	(0.10%)
Employee stock ownership plan deduction	(0.00%)	(0.00%)	(0.00%)
Other, net	0.30%	0.10%	0.30%
Effective tax rate	38.20%	39.50%	39.50%

Income Taxes (The Companies Def

Income Taxes (The Companies Deferred Income Taxes Components) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Income Tax Contingency [Line Items]
Total deferred income tax assets	$ 1,152	$ 2,023
Total deferred income tax liabilities	8,552	8,663
Total deferred income tax liabilities	7,400	6,640
Total deferred income taxes:
Plant and equipment, primarily depreciation method and basis differences	6,299	5,895
Nuclear decommissioning	1,158	1,241
Deferred state income taxes	646	659
Federal benefit of deferred state income taxes	(226)	(231)
Deferred fuel, purchased energy and gas costs	(1)	27
Pension benefits	291	272
Other postretirement benefits	(15)	(17)
Loss and credit carryforwards	(1,004)	(1,434)
Valuation allowances	73	87
Partnership basis differences	367	304
Other	(188)	(163)
Total deferred income tax liabilities	7,400	6,640
Virginia Electric and Power Company
Income Tax Contingency [Line Items]
Total deferred income tax assets	164	500
Total deferred income tax liabilities	4,805	4,915
Total deferred income tax liabilities	4,641	4,415
Total deferred income taxes:
Plant and equipment, primarily depreciation method and basis differences	4,133	3,965
Nuclear decommissioning	378	474
Deferred state income taxes	302	299
Federal benefit of deferred state income taxes	(106)	(105)
Deferred fuel, purchased energy and gas costs	(3)	18
Pension benefits	(99)	(77)
Other postretirement benefits	30	13
Loss and credit carryforwards	(53)	(116)
Valuation allowances	0	0
Partnership basis differences	0	0
Other	59	(56)
Total deferred income tax liabilities	4,641	4,415
Dominion Gas Holdings, LLC
Income Tax Contingency [Line Items]
Total deferred income tax assets	129	227
Total deferred income tax liabilities	2,343	2,289
Total deferred income tax liabilities	2,214	2,062
Total deferred income taxes:
Plant and equipment, primarily depreciation method and basis differences	1,541	1,417
Nuclear decommissioning	0	0
Deferred state income taxes	205	207
Federal benefit of deferred state income taxes	(72)	(72)
Deferred fuel, purchased energy and gas costs	1	7
Pension benefits	613	567
Other postretirement benefits	(7)	(12)
Loss and credit carryforwards	(4)	(10)
Valuation allowances	0	0
Partnership basis differences	41	42
Other	(104)	(84)
Total deferred income tax liabilities	$ 2,214	$ 2,062

Income Taxes (Unrecognized Tax

Income Taxes (Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1	$ 145	$ 222	$ 293
Increases-prior period positions	2	24	17
Decreases-prior period positions	(40)	(26)	(99)
Increases-current period positions	8	16	30
Decreases-current period positions	0	0	(5)
Settlements with tax authorities	(5)	0	(2)
Expiration of statutes of limitations	(7)	(91)	(12)
Balance at December 31	103	145	222
Virginia Electric and Power Company
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1	36	39	57
Increases-prior period positions	0	2	12
Decreases-prior period positions	(25)	(16)	(42)
Increases-current period positions	1	11	14
Decreases-current period positions	0	0	0
Settlements with tax authorities	0	0	(2)
Expiration of statutes of limitations	0	0	0
Balance at December 31	12	36	39
Dominion Gas Holdings, LLC
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1	29	29	30
Increases-prior period positions	0	0	0
Decreases-prior period positions	0	0	(1)
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	$ 29

Income Taxes (Earliest Tax Year

Income Taxes (Earliest Tax Year) (Details)	12 Months Ended
	Dec. 31, 2015
Pennsylvania
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,010	[1]
Connecticut
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,012
Virginia
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,012	[2]
West Virginia
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,012	[1]
New York
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,007	[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) $ in Millions	12 Months Ended
	Dec. 31, 2013USD ($)
Current:
Federal	$ (274)
State	(41)
Total current benefit	(315)
Deferred:
Federal	232
State	40
Total deferred expense	272
Total income tax benefit	$ (43)

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value, Option, Quantitative Disclosures) (Details) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)$ / gal$ / MMBTU$ / MWh	Dec. 31, 2014USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		$ 388	$ 719
Derivative liabilities		343	794
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		114
Derivative liabilities		19
Level 3 | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	[1]	97
Derivative liabilities	[1]	9
Level 3 | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		4
Derivative liabilities		7
Level 3 | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		9
Derivative liabilities		3
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]	$ 4
Level 3 | Liabilities: | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	(2)
Level 3 | Liabilities: | Minimum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	2
Price Volatility	[4]	25.00%
Level 3 | Liabilities: | Minimum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MWh	[3]	(9)
Level 3 | 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 | $ / MMBTU	[3],[5]	2
Level 3 | Liabilities: | Weighted Average | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3],[5]	3
Price Volatility	[4],[5]	35.00%
Level 3 | 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 | $ / MWh	[3],[5]	2
Level 3 | Liabilities: | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	3
Level 3 | Liabilities: | Maximum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	5
Price Volatility	[4]	58.00%
Level 3 | Liabilities: | Maximum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MWh	[3]	9
Level 3 | Assets: | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	(2)
Credit Spread	[6]	1.00%
Level 3 | Assets: | Minimum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	2
Price Volatility	[4]	25.00%
Level 3 | Assets: | Minimum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MWh	[3]	0
Level 3 | Assets: | Minimum | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / gal	[3]	(2)
Level 3 | 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 | $ / MMBTU	[3],[5]	(1)
Credit Spread	[5],[6]	3.00%
Level 3 | Assets: | Weighted Average | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3],[5]	3
Price Volatility	[4],[5]	37.00%
Level 3 | 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 | $ / gal	[3],[5]	1
Level 3 | 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 | $ / MWh	[3],[5]	1
Level 3 | Assets: | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	8
Credit Spread	[6]	6.00%
Level 3 | Assets: | Maximum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[3]	3
Price Volatility	[4]	58.00%
Level 3 | Assets: | Maximum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MWh	[3]	2
Level 3 | Assets: | Maximum | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / gal	[3]	14
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		$ 11	2
Derivative liabilities		14	9
Dominion Gas Holdings, LLC | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		6
Dominion Gas Holdings, LLC | Level 3 | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		$ 6
Dominion Gas Holdings, LLC | Level 3 | Assets: | Minimum | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / gal	[7]	0
Dominion Gas Holdings, LLC | Level 3 | 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 | $ / gal	[7],[8]	1
Dominion Gas Holdings, LLC | Level 3 | Assets: | Maximum | Liquids | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / gal	[7]	1
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		$ 127	113
Derivative liabilities		86	$ 87
Virginia Electric and Power Company | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		101
Derivative liabilities		8
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	[9]	92
Virginia Electric and Power Company | Level 3 | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		5
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		9
Derivative liabilities		$ 3
Virginia Electric and Power Company | Level 3 | Liabilities: | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[10]	(9)
Virginia Electric and Power Company | Level 3 | Liabilities: | Minimum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[10]	2
Price Volatility	[11]	32.00%
Virginia Electric and Power Company | Level 3 | Liabilities: | Weighted Average | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[10],[12]	3
Price Volatility	[11],[12]	35.00%
Virginia Electric and Power Company | Level 3 | 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 | $ / MWh	[10],[12]	2
Virginia Electric and Power Company | Level 3 | Liabilities: | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[10]	9
Virginia Electric and Power Company | Level 3 | Liabilities: | Maximum | Gas | Physical and Financial Options:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[10]	5
Price Volatility	[11]	38.00%
Virginia Electric and Power Company | Level 3 | Assets: | Minimum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[10]	(2)
Credit Spread	[13]	1.00%
Virginia Electric and Power Company | Level 3 | Assets: | Minimum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MWh	[10]	(2)
Virginia Electric and Power Company | Level 3 | 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 | $ / MMBTU	[10],[12]	(1)
Credit Spread	[12],[13]	3.00%
Virginia Electric and Power Company | Level 3 | 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 | $ / MWh	[10],[12]	1
Virginia Electric and Power Company | Level 3 | Assets: | Maximum | Gas | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MMBTU	[10]	4
Credit Spread	[13]	6.00%
Virginia Electric and Power Company | Level 3 | Assets: | Maximum | FTRs | Physical and Financial Forwards and Futures:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Market Price | $ / MWh	[10]	14
[1]	Includes basis.
[2]	Includes NGLs and oil.
[3]	Represents market prices beyond defined terms for Levels 1 and 2.
[4]	Represents volatilities unrepresented in published markets
[5]	Averages weighted by volume.
[6]	Represents credit spreads unrepresented in published markets.
[7]	Represents market prices beyond defined terms for Levels 1 and 2.
[8]	Averages weighted by volume.
[9]	Includes basis.
[10]	Represents market prices beyond defined terms for Levels 1 and 2.
[11]	Represents volatilities unrepresented in published markets.
[12]	Averages weighted by volume.
[13]	Represents credit spreads unrepresented in published markets.

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details) $ in Millions	1 Months Ended	3 Months Ended
	Jun. 30, 2013USD ($)Project	Dec. 31, 2015USD ($)
Fair Value, Measurements, Nonrecurring | Gas, Transmission and Distribution Equipment | 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
Fair Value, Measurements, Nonrecurring | Gas, Transmission and Distribution Equipment | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Estimated fair value	$ 1
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number of development projects canceled | Project	2
Dominion Gas Holdings, LLC | Fair Value, Measurements, Nonrecurring | 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 (Assets

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		$ 388	$ 719
Derivative liabilities		343	794
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		114
Derivative liabilities		19
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		4,589	4,938
Total liabilities		343	794
Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		364	695
Derivative liabilities		160	592
Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		24	24
Derivative liabilities		183	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	[1]	2,547	2,669
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	[1]	10	12
Fair Value, Measurements, Recurring | Equity securities: | Other | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	5	6
Fair Value, Measurements, Recurring | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	63
Fair Value, Measurements, Recurring | Fixed Income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	437	441
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	[1]	659	609
Fair Value, Measurements, Recurring | Fixed Income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	376	395
Fair Value, Measurements, Recurring | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	100	74
Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	4	13
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		3,086	3,112
Total liabilities		0	3
Fair Value, Measurements, Recurring | Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1	3
Derivative liabilities		0	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	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	[1]	2,547	2,669
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	[1]	10	12
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	[1]	5	6
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	63
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	[1]	0	0
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	[1]	458	419
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	[1]	0	0
Fair Value, Measurements, Recurring | Level 1 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	2	3
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		1,389	1,701
Total liabilities		324	773
Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		249	567
Derivative liabilities		141	571
Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		24	24
Derivative liabilities		183	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	[1]	0	0
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	[1]	0	0
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	[1]	0	0
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0
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	[1]	437	441
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	[1]	201	190
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	[1]	376	395
Fair Value, Measurements, Recurring | Level 2 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	100	74
Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	2	10
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		114	125
Total liabilities		19	18
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		114	125
Derivative liabilities		19	18
Fair Value, Measurements, Recurring | Level 3 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		0	0
Derivative liabilities		0	0
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large Cap | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
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	[1]	0	0
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	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0
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	[1]	0	0
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	[1]	0	0
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	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		127	113
Derivative liabilities		86	87
Virginia Electric and Power Company | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		101
Derivative liabilities		8
Virginia Electric and Power Company | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		1,996	1,952
Total liabilities		86	87
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		114	113
Derivative liabilities		27	15
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		13
Derivative liabilities		59	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	[2]	1,100	1,157
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	63
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	[2]	238	250
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	[2]	259	198
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	[2]	175	211
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	[2]	34	23
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		1,343	1,294
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	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	[2]	1,100	1,157
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	63
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	[2]	0	0
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	[2]	180	137
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	[2]	0	0
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	[2]	0	0
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	552
Total liabilities		78	83
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		13	7
Derivative liabilities		19	11
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		13
Derivative liabilities		59	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	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0
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	[2]	238	250
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	[2]	79	61
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	[2]	175	211
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	[2]	34	23
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		101	106
Total liabilities		8	4
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		101	106
Derivative liabilities		8	4
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	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	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | REIT | U.S.:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0
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	[2]	0	0
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	[2]	0	0
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	[2]	0	0
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	[2]	0	0
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		11	2
Derivative liabilities		14	9
Dominion Gas Holdings, LLC | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		6
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		11	2
Total liabilities		14	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		11	2
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		14	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	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
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 liabilities		0	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		5	0
Total liabilities		14	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		5	0
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 liabilities		14	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		6	2
Total liabilities		0	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		6	2
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 liabilities		$ 0	$ 0
[1]	Includes investments held in the nuclear decommissioning and rabbi trusts.
[2]	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 ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Included in earnings		$ (5)	$ 97	$ (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		2	6	0
Commodity | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Beginnning balance		107	(16)	25
Included in earnings		(5)	97	(9)
Included in other comprehensive income (loss)		(9)	7	1
Included in regulatory assets/liabilities		(4)	109	(9)
Settlements		9	(88)	(23)
Transfers out of Level 3	[1]	(3)	(2)	(1)
Ending balance		95	107	(16)
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		2	6	0
NGL's | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Transfers out of Level 3		(9)
Virginia Electric and Power Company | Commodity | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Beginnning balance		102	(7)	2
Included in earnings		(13)	96	(17)
Included in regulatory assets/liabilities		(5)	109	(9)
Settlements		13	(96)	17
Transfers out of Level 3		(4)	0	0
Ending balance		93	102	(7)
Dominion Gas Holdings, LLC | Commodity | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Beginnning balance		2	(6)	(12)
Included in earnings		1	2	1
Included in other comprehensive income (loss)		(5)	10	3
Settlements		(1)	(4)	2
Transfers out of Level 3	[2]	9	0	0
Ending balance		6	$ 2	$ (6)
Dominion Gas Holdings, LLC | NGL's | Level 3 | Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]
Transfers out of Level 3		$ (9)
[1]	In March 2015, Dominion changed the classification of certain short term NGL derivatives from Level 3 to Level 2 due to an increase in liquidity in financial forward markets. The transfers out of Level 3 that relate to NGLs for the year ended December 31, 2015 were $9 million.
[2]	In March 2015, Dominion Gas changed the classification of certain short term NGL derivatives from Level 3 to Level 2 due to an increase in liquidity in financial forward markets. The transfers out of Level 3 that relate to NGLs for the year ended December 31, 2015 were $9 million.

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Gains and Losses Included in the Level 3 Fair Value Category) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	$ (5)	$ 97	$ (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	2	6	0
Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	6	4	11
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	4	1
Electric Fuel and Other Energy-Related Purchases
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	(11)	97	(19)
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
Purchased Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	0	(4)	(1)
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	$ 0	$ 1	$ (1)

Fair Value Measurements (Financ

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year		$ 25,473
Valuation of certain fair value hedges		7	$ 19
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[1]	21,998	19,723
Junior subordinated notes	[2]	1,358	1,374
Remarketable subordinated notes	[2]	2,086	2,083
Estimated Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[1],[3]	23,210	21,881
Junior subordinated notes	[2],[3]	1,192	1,396
Remarketable subordinated notes	[2],[3]	2,129	2,362
Virginia Electric and Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year		9,425
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	[2]	9,425	8,937
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	[2],[3]	10,400	10,293
Dominion Gas Holdings, LLC
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year		3,300
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	[2]	3,292	2,594
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	[2],[3]	$ 3,299	$ 2,672
[1]	Carrying amount includes amounts which represent the unamortized discount and/or premium. At December 31, 2015, and 2014, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of $7 million and $19 million, respectively.
[2]	Carrying amount includes amounts which represent the unamortized discount and/or premium.
[3]	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 Account78

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$ 379	$ 704
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	379	704
Total derivatives, not subject to a master netting or similar arrangement	9	15
Gross Amounts of Recognized Assets, Total	388	719
Derivative Asset	388	719
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	141	348
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	34
Net Amounts	238	322
Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	24	24
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	24	24
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	22	16
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	2	8
Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	217	382
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	217	382
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	37	34
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	34
Net Amounts	180	314
Commodity | Exchange
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	138	298
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	138	298
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	82	298
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	56	0
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	114	106
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	114	106
Total derivatives, not subject to a master netting or similar arrangement	13	7
Gross Amounts of Recognized Assets, Total	127	113
Derivative Asset	127	113
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	13	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	101	102
Virginia Electric and Power Company | Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	13	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	13	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	10	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	3	0
Virginia Electric and Power Company | Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	101	106
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	101	106
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	98	102
Dominion Gas Holdings, LLC
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	11	2
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	11	2
Derivative Asset	11	2
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	11	2
Dominion Gas Holdings, LLC | Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	11	2
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	11	2
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	$ 11	$ 2

Derivatives and Hedge Account79

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$ 335	$ 782
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	335	782
Total derivatives, not subject to a master netting or similar arrangement	8	12
Gross Amounts of Recognized Liabilities, Total	343	794
Derivative liabilities	343	794
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	141	348
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	196
Net Amounts	194	238
Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	183	202
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	183	202
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	22	16
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	161	186
Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	70	87
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	70	87
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	37	34
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	1
Net Amounts	33	52
Commodity | Exchange
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	82	493
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	82	493
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	82	298
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	195
Net Amounts	0	0
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	64	80
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	64	80
Total derivatives, not subject to a master netting or similar arrangement	22	7
Gross Amounts of Recognized Liabilities, Total	86	87
Derivative liabilities	86	87
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	13	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	51	76
Virginia Electric and Power Company | Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	59	72
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	59	72
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	10	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	49	72
Virginia Electric and Power Company | Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	5	8
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	5	8
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0	0
Net Amounts	2	4
Dominion Gas Holdings, LLC
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	14	9
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	14	9
Derivative liabilities	14	9
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	14	9
Dominion Gas Holdings, LLC | Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	14	9
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	14	9
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	$ 14	$ 9

Derivatives and Hedge Account80

Derivatives and Hedge Accounting Activities (Volume of our Derivative Activity) (Details) gal in Thousands, MMcf in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)MWhMWMMcfgal
Fixed Price - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	80	[1]
Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	19	[1]
Basis - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	216
Basis - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	554
Fixed Price - Electricity - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh	15,661,078
Fixed Price - Electricity - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh	0
Financial Transmission Rights - Electricity- Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh	33,350,993
Financial Transmission Rights - Electricity- Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh	0
Capacity - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of capacity (MW) | MW	7,600
Capacity - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of capacity (MW) | MW	0
Liquids - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal	83,076	[2]
Liquids - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal	18,606	[2]
Interest Rate - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	$ 2,950
Interest Rate - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	$ 3,100
Virginia Electric and Power Company | Fixed Price - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	32	[3]
Virginia Electric and Power Company | Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	10	[3]
Virginia Electric and Power Company | Basis - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	102
Virginia Electric and Power Company | Basis - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	509
Virginia Electric and Power Company | Financial Transmission Rights - Electricity- Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh	30,383,934
Virginia Electric and Power Company | Financial Transmission Rights - Electricity- Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh	0
Virginia Electric and Power Company | Capacity - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of capacity (MW) | MW	7,600
Virginia Electric and Power Company | Capacity - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of capacity (MW) | MW	0
Virginia Electric and Power Company | Interest Rate - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	$ 900
Virginia Electric and Power Company | Interest Rate - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	$ 1,100
Dominion Gas Holdings, LLC | Liquids - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal	77,364
Dominion Gas Holdings, LLC | Liquids - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal	13,818
Dominion Gas Holdings, LLC | Interest Rate - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	$ 250
Dominion Gas Holdings, LLC | Interest Rate - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	$ 0
[1]	Includes options.
[2]	Includes NGLs and oil.
[3]	Includes options.

Derivatives and Hedge Account81

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (176)	$ (178)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	66
Commodity | Gas
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	(7)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$ (7)
Maximum Term	22 months
Commodity | Electricity
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ 76
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$ 76
Maximum Term	12 months
Commodity | Other
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ 6
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$ 6
Maximum Term	15 months
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (251)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$ (9)
Maximum Term	387 months
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (17)	$ (20)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	6
Dominion Gas Holdings, LLC | Commodity | Other
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	7
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$ 6
Maximum Term	15 months
Dominion Gas Holdings, LLC | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (24)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	$ 0
Maximum Term	348 months

Derivatives and Hedge Account82

Derivatives and Hedge Accounting Activities (Fair Values of our Derivatives) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		$ 388	$ 719
Derivative liabilities		343	794
Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		255	536
Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		252	523
Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		3	13
Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[1]	133	183
Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		112	172
Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		21	11
Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		312	591
Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		148	491
Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		164	100
Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[2]	31	203
Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		12	101
Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		19	102
Fair Value - Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		128	376
Derivative liabilities		215	481
Fair Value - Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		104	294
Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		101	281
Fair Value - Derivatives under Hedge Accounting | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		3	13
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[1]	24	82
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		3	71
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		21	11
Fair Value - Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		196	324
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		32	224
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		164	100
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[2]	19	157
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		0	55
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		19	102
Fair Value - Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		260	343
Derivative liabilities		128	313
Fair Value - Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		151	242
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		151	242
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0	0
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[1]	109	101
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		109	101
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0	0
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		116	267
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		116	267
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		0	0
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[2]	12	46
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		12	46
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		0	0
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		127	113
Derivative liabilities		86	87
Virginia Electric and Power Company | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[3]	18	51
Virginia Electric and Power Company | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		18	51
Virginia Electric and Power Company | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[4]	109	62
Virginia Electric and Power Company | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		96	62
Virginia Electric and Power Company | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		13
Virginia Electric and Power Company | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		80	60
Virginia Electric and Power Company | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		23	15
Virginia Electric and Power Company | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		57	45
Virginia Electric and Power Company | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[5]	6	27
Virginia Electric and Power Company | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		4	27
Virginia Electric and Power Company | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		2
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		13	0
Derivative liabilities		59	75
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[3]	0	0
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0	0
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[4]	13	0
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0	0
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		13
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		57	48
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		0	3
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		57	45
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[5]	2	27
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		0	27
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		2
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		114	113
Derivative liabilities		27	12
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[3]	18	51
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		18	51
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[4]	96	62
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		96	62
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		23	12
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		23	12
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		0	0
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[5]	4	0
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		4	0
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		0
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		11	2
Derivative liabilities		14	9
Dominion Gas Holdings, LLC | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[6]	10	2
Dominion Gas Holdings, LLC | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		10	2
Dominion Gas Holdings, LLC | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[7]	1
Dominion Gas Holdings, LLC | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		1
Dominion Gas Holdings, LLC | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[8]	14
Dominion Gas Holdings, LLC | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		14
Dominion Gas Holdings, LLC | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[9]		9
Dominion Gas Holdings, LLC | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities			9
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		11	2
Derivative liabilities		14	9
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[6]	10	2
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		10	2
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[7]	1
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		1
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[8]	14
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		14
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[9]		9
Dominion Gas Holdings, LLC | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities			9
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0	0
Derivative liabilities		0	0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[6]	0	0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0	0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets	[7]	0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative assets		0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[8]	0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities		$ 0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative liabilities	[9]		0
Dominion Gas Holdings, LLC | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative 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]	Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.
[8]	Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.
[9]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.

Derivatives and Hedge Account83

Derivatives and Hedge Accounting Activities (Gains and Losses on our Derivatives in Cash Flow Hedging Relationships) (Details) - Cash Flow Hedges - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	$ 184	$ 37	$ (404)
Amount of Gain (Loss) Reclassified from AOCI to Income		176	(152)	(130)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	(9)	(85)	86
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	230	245	(481)
Amount of Gain (Loss) Reclassified from AOCI to Income		187	(136)	(115)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	4	(4)	5
Commodity | Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income		203	(130)	(58)
Commodity | Purchased gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income		(15)	(13)	(47)
Commodity | Electric fuel and other energy-related purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income		(1)	7	(10)
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1],[3]	(46)	(208)	77
Amount of Gain (Loss) Reclassified from AOCI to Income	[3]	(11)	(16)	(15)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2],[3]	(13)	(81)	81
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[4]	(3)	(6)	9
Amount of Gain (Loss) Reclassified from AOCI to Income		(1)	5	0
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[5]	(9)	(85)	86
Virginia Electric and Power Company | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[4]	0	4	0
Amount of Gain (Loss) Reclassified from AOCI to Income		(1)	5	0
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[5]	4	(4)	5
Virginia Electric and Power Company | Commodity | Electric Fuel and Other Energy-Related Purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income		(1)	5	0
Virginia Electric and Power Company | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[4],[6]	(3)	(10)	9
Amount of Gain (Loss) Reclassified from AOCI to Income	[6]	0	0	0
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[5],[6]	(13)	(81)	81
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[7]	10	(50)	66
Amount of Gain (Loss) Reclassified from AOCI to Income		6	(13)	(16)
Dominion Gas Holdings, LLC | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[7]	16	12	(2)
Amount of Gain (Loss) Reclassified from AOCI to Income		6	(12)	(16)
Dominion Gas Holdings, LLC | Commodity | Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income		6	2	(2)
Dominion Gas Holdings, LLC | Commodity | Purchased gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from AOCI to Income			(14)	(14)
Dominion Gas Holdings, LLC | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[7],[8]	(6)	(62)	68
Amount of Gain (Loss) Reclassified from AOCI to Income	[8]	$ 0	$ (1)	$ 0
[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 Account84

Derivatives and Hedge Accounting Activities (Gains and Losses on our Derivatives Not Designated as Hedging Instruments) (Details) - Derivatives not designated as hedging instruments - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	$ (5)	$ (248)	$ (83)
Commodity | Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	24	(310)	(45)
Commodity | Purchased gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(14)	(51)	(9)
Commodity | Electric fuel and other energy-related purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(14)	113	(29)
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1],[2]	(1)	0	0
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[3]	(13)	105	(16)
Virginia Electric and Power Company | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[3],[4]	(13)	105	(16)
Dominion Gas Holdings, LLC | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		6	0	0
Dominion Gas Holdings, LLC | Commodity | Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		$ 6	$ 0	$ 0
[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 ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended								12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings Per Share [Abstract]
Net income attributable to Dominion		$ 357	$ 593	$ 413	$ 536	$ 243	$ 529	$ 159	$ 379	$ 1,899	$ 1,310	$ 1,697
Average shares of common stock outstanding-Basic										592.4	582.7	578.7
Net effect of potentially dilutive securities	[1]									1.3	1.8	0.8
Average shares of common stock outstanding-Diluted										593.7	584.5	579.5
Earnings Per Common Share-Basic (in dollars per share)		$ 0.60	$ 1	$ 0.70	$ 0.91	$ 0.42	$ 0.91	$ 0.27	$ 0.65	$ 3.21	$ 2.25	$ 2.93
Earnings Per Common Share-Diluted (in dollars per share)		$ 0.60	$ 1	$ 0.70	$ 0.91	$ 0.42	$ 0.90	$ 0.27	$ 0.65	$ 3.20	$ 2.24	$ 2.93
[1]	Dilutive securities consist primarily of the 2013 Equity Units for 2015, the 2013 Equity Units and contingently convertible senior notes for 2014, and contingently convertible senior notes for 2013. Dominion redeemed all of its contingently convertible senior notes in 2014. See Note 17 for more information.

Investments (Narrative) (Detail

Investments (Narrative) (Details) $ in Millions	1 Months Ended				3 Months Ended		12 Months Ended
	Sep. 30, 2014Membermi	Mar. 31, 2014USD ($)	Jan. 31, 2014USD ($)	Mar. 31, 2013USD ($)	Dec. 31, 2013USD ($)	Sep. 30, 2013USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Gain (Loss) on Investments [Line Items]
Equity earnings on investments							$ 56	$ 46	$ 14
Company received distribution from Fowler Ridge in connection with non-recourse permanent financing							83	60	33
Carrying amount of Company's investments exceeded its shares of underlying equity							234	126
Equity method investment goodwill							162	39
Proceeds from Blue Racer							0	85	160
Write off of goodwill								42
Finite Lived Equity Method Investment Basis Difference
Gain (Loss) on Investments [Line Items]
Carrying amount of Company's investments exceeded its shares of underlying equity							72	87
Blue Racer
Gain (Loss) on Investments [Line Items]
Amount of consideration		$ 84
Proceeds from Blue Racer		84		$ 47
Increase in equity method investment						$ 473
Increase in equity method investment			$ 155
Realignment of nonregulated retail energy marketing to the Dominion Energy segment			$ 6
Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline | Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)	45.00%
Length of FERC regulated interstate natural gas pipeline | mi	600
Number of members | Member	4
Duration of contract	20 years
Atlantic Coast Pipeline | Pipelines | Duke Energy | Jointly Owned Natural Gas Pipeline | Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)	40.00%
Atlantic Coast Pipeline | Pipelines | Piedmont | Jointly Owned Natural Gas Pipeline | Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)	10.00%
Atlantic Coast Pipeline | Pipelines | AGL | Jointly Owned Natural Gas Pipeline | Distribution
Gain (Loss) on Investments [Line Items]
Ownership interest (percentage)	5.00%
Other operations and maintenance expense | Blue Racer
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							23	21	22
Company received distribution from Fowler Ridge in connection with non-recourse permanent financing							28	20	19
Carrying amount of Company's investments exceeded its shares of underlying equity							8	8
Proceeds from Blue Racer							0	1	$ 78
Write off of goodwill								3
Dominion Gas Holdings, LLC | Blue Racer
Gain (Loss) on Investments [Line Items]
Proceeds from Blue Racer		17			30	78
Extinguishment of affiliated current borrowings		67
Dominion Gas Holdings, LLC | Other operations and maintenance expense | Blue Racer
Gain (Loss) on Investments [Line Items]
Gain from sale		59			3	74
After tax gain on sale		35			$ 2	$ 41
Write off of goodwill		$ 3
Categories of Investments, Marketable Securities, Trading Securities
Gain (Loss) on Investments [Line Items]
Investments held in our rabbi trusts							$ 100	$ 110

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 ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Investment Holdings [Line Items]
Total Unrealized Gains	[1]	$ 1,258	$ 1,408
Total Unrealized Losses	[1],[2]	(11)	(6)
Nuclear decommissioning trust funds		4,183	4,196
Total Amortized Cost		2,936	2,794
Net assets related to pending sales and purchases of securities		12	3
Fair value of securities in an unrealized loss position		592	379
Virginia Electric and Power Company
Investment Holdings [Line Items]
Total Unrealized Gains	[3]	548	619
Total Unrealized Losses	[3],[4]	(7)	(3)
Nuclear decommissioning trust funds		1,945	1,930
Total Amortized Cost		1,404	1,314
Net assets related to pending sales and purchases of securities		8	6
Fair value of securities in an unrealized loss position		281	170
Cost method investments
Investment Holdings [Line Items]
Other investments and securities, at cost		70	86
Total Unrealized Gains	[1]	0	0
Total Unrealized Losses	[1]	0	0
Nuclear decommissioning trust funds		70	86
Cost method investments | Virginia Electric and Power Company
Investment Holdings [Line Items]
Other investments and securities, at cost		70	86
Total Unrealized Gains	[3]	0	0
Total Unrealized Losses	[3]	0	0
Nuclear decommissioning trust funds		70	86
Cash equivalents and other
Investment Holdings [Line Items]
Other investments and securities, at cost	[5]	14	16
Total Unrealized Gains	[1],[5]	0	0
Total Unrealized Losses	[1],[5]	0	0
Nuclear decommissioning trust funds	[5]	14	16
Cash equivalents and other | Virginia Electric and Power Company
Investment Holdings [Line Items]
Other investments and securities, at cost	[6]	8	6
Total Unrealized Gains	[3],[6]	0	0
Total Unrealized Losses	[3],[6]	0	0
Nuclear decommissioning trust funds	[6]	8	6
Equity securities: | REIT
Investment Holdings [Line Items]
Amortized Cost		59
Total Unrealized Gains	[1]	4
Total Unrealized Losses	[1]	0
Nuclear decommissioning trust funds		63
Equity securities: | REIT | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost		59
Total Unrealized Gains	[3]	4
Total Unrealized Losses	[3]	0
Nuclear decommissioning trust funds		63
Corporate debt instruments
Investment Holdings [Line Items]
Amortized Cost		433	424
Total Unrealized Gains	[1]	11	19
Total Unrealized Losses	[1]	(7)	(2)
Nuclear decommissioning trust funds		437	441
Corporate debt instruments | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost		237	242
Total Unrealized Gains	[3]	5	9
Total Unrealized Losses	[3]	(4)	(1)
Nuclear decommissioning trust funds		238	250
U.S. Treasury securities and agency debentures
Investment Holdings [Line Items]
Amortized Cost		654	597
Total Unrealized Gains	[1]	8	13
Total Unrealized Losses	[1]	(4)	(4)
Nuclear decommissioning trust funds		658	606
U.S. Treasury securities and agency debentures | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost		260	197
Total Unrealized Gains	[3]	1	3
Total Unrealized Losses	[3]	(2)	(2)
Nuclear decommissioning trust funds		259	198
State and municipal
Investment Holdings [Line Items]
Amortized Cost		312	332
Total Unrealized Gains	[1]	22	23
Total Unrealized Losses	[1]	0	0
Nuclear decommissioning trust funds		334	355
State and municipal | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost		162	197
Total Unrealized Gains	[3]	13	13
Total Unrealized Losses	[3]	(1)	0
Nuclear decommissioning trust funds		174	210
Other securities
Investment Holdings [Line Items]
Amortized Cost		99	66
Total Unrealized Gains	[1]	0	0
Total Unrealized Losses	[1]	0	0
Nuclear decommissioning trust funds		99	66
Other securities | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost		34	23
Total Unrealized Gains	[3]	0	0
Total Unrealized Losses	[3]	0	0
Nuclear decommissioning trust funds		34	23
U.S.: | Equity securities: | Large Cap
Investment Holdings [Line Items]
Amortized Cost		1,295	1,273
Total Unrealized Gains	[1]	1,213	1,353
Total Unrealized Losses	[1]	0	0
Nuclear decommissioning trust funds		2,508	2,626
U.S.: | Equity securities: | Large Cap | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost		574	563
Total Unrealized Gains	[3]	525	594
Total Unrealized Losses	[3]	0	0
Nuclear decommissioning trust funds		$ 1,099	$ 1,157
[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 $592 million and $379 million at December 31, 2015 and 2014, respectively.
[3]	Included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
[4]	The fair value of securities in an unrealized loss position was $281 million and $170 million at December 31, 2015 and 2014, respectively.
[5]	Includes pending sales of securities of $12 million and $3 million at December 31, 2015 and 2014, respectively.
[6]	Includes pending sales of securities of $8 million and $6 million at December 31, 2015 and 2014, respectively.

Investments (Fair Value of our

Investments (Fair Value of our Marketable Debt Securities by Contractual Maturity) (Details) $ in Millions	Dec. 31, 2015USD ($)
Schedule of Available-for-sale Securities [Line Items]
Due in one year or less	$ 208
Due after one year through five years	396
Due after five years through ten years	412
Due after ten years	512
Total	1,528
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Due in one year or less	67
Due after one year through five years	166
Due after five years through ten years	236
Due after ten years	236
Total	$ 705

Investments (Selected Informati

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Available-for-sale securities:
Proceeds from sales		$ 1,340	$ 1,235	$ 1,476
Realized gains	[1]	219	171	157
Realized losses	[1]	84	30	33
Virginia Electric and Power Company
Available-for-sale securities:
Proceeds from sales		639	549	572
Realized gains	[2]	110	73	52
Realized losses	[2]	$ 43	$ 12	$ 14
[1]	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
[2]	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.

Investments (Recorded Other-Tha

Investments (Recorded Other-Than-Temporary Impairment Losses on Investments) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]
Total other-than-temporary impairment losses	[1]	$ 66	$ 21	$ 31
Losses recorded to nuclear decommissioning trust regulatory liability		(26)	(5)	(13)
Losses recognized in other comprehensive income (before taxes)		(9)	(3)	(10)
Net impairment losses recognized in earnings		31	13	8
Other-than-temporary impairment losses for debt securities		9	3	18
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Total other-than-temporary impairment losses	[2]	36	8	15
Losses recorded to nuclear decommissioning trust regulatory liability		(26)	(4)	(13)
Losses recognized in other comprehensive income (before taxes)		(6)	(2)	(1)
Net impairment losses recognized in earnings		4	2	1
Other-than-temporary impairment losses for debt securities		$ 6	$ 2	$ 9
[1]	Amounts include other-than-temporary impairment losses for debt securities of $9 million, $3 million and $18 million at December 31, 2015, 2014 and 2013, respectively.
[2]	Comprised of Dominion Midstream's interest of 25.93% and Dominion Gas' interest of 24.72%. See Note 15 for more information.

Investments (Investments Under

Investments (Investments Under Equity Method of Accounting) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Investment Balance		$ 1,320	$ 1,081
Commitment to invest in clean power and technology		$ 50
Blue Racer
Schedule of Equity Method Investments [Line Items]
Ownership%		50.00%
Investment Balance		$ 661	671
Description		Midstream gas and related services
Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%	[1]	50.65%
Investment Balance		$ 324	107
Description		Gas transmission system
Fowler Ridge
Schedule of Equity Method Investments [Line Items]
Ownership%		50.00%
Investment Balance		$ 125	134
Description		Wind-powered merchant generation facility
NedPower
Schedule of Equity Method Investments [Line Items]
Ownership%		50.00%
Investment Balance		$ 119	128
Description		Wind-powered merchant generation facility
Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Ownership%		45.00%
Investment Balance		$ 59	19
Description		Gas transmission system
Other
Schedule of Equity Method Investments [Line Items]
Investment Balance	[2]	$ 32	22
Dominion Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Investment Balance		$ 102	107
Dominion Gas Holdings, LLC | Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%	[1]	24.72%
Investment Balance		$ 102	$ 107
Description		Gas transmission system
Dominion Midstream Partners, LP | Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%	[1]	25.93%
[1]	Comprised of Dominion Midstream's interest of 25.93% and Dominion Gas' interest of 24.72%. See Note 15 for more information.
[2]	Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018.

Property, Plant and Equipment92

Property, Plant and Equipment (Property, Plant and Equipment) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Utility:
Generation	$ 15,656	$ 15,193
Transmission	11,461	9,897
Distribution	13,128	12,354
Storage	2,460	2,350
Nuclear fuel	1,464	1,411
Gas gathering and processing	799	791
General and other	927	845
Other-including plant under construction	5,550	3,633
Total utility	51,445	46,474
Nonutility:
Merchant generation-nuclear	1,339	1,267
Merchant generation-other	2,683	2,023
Nuclear fuel	938	860
Other-including plant under construction	1,371	782
Total nonutility	6,331	4,932
Total property, plant and equipment	57,776	51,406
Virginia Electric and Power Company
Utility:
Generation	15,656	15,193
Transmission	6,963	5,884
Distribution	10,048	9,526
Nuclear fuel	1,464	1,411
General and other	709	697
Other-including plant under construction	2,793	2,464
Total utility	37,633	35,175
Nonutility:
Total nonutility	6	5
Total property, plant and equipment	37,639	35,180
Dominion Gas Holdings, LLC
Utility:
Transmission	3,804	3,690
Distribution	2,765	2,530
Storage	1,583	1,466
Gas gathering and processing	797	786
General and other	165	111
Plant under construction	443	179
Total utility	9,557	8,762
Nonutility:
E&P properties being amortized and other	136	140
Total nonutility	136	140
Total property, plant and equipment	$ 9,693	$ 8,902

Property, Plant and Equipment93

Property, Plant and Equipment (Share of Jointly-Owned Power Stations) (Details) $ in Millions	Dec. 31, 2015USD ($)
Millstone Unit 3
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest (percentage)	93.50%	[1]
Plant in service	$ 1,149	[1]
Accumulated depreciation	(320)	[1]
Nuclear fuel	521	[1]
Accumulated amortization of nuclear fuel	(364)	[1]
Plant under construction	$ 55	[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	$ 1,049	[2]
Accumulated depreciation	(567)	[2]
Nuclear fuel	0	[2]
Accumulated amortization of nuclear fuel	0	[2]
Plant under construction	$ 12	[2]
Virginia Electric and Power Company | North Anna
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest (percentage)	88.40%	[2]
Plant in service	$ 2,452	[2]
Accumulated depreciation	(1,177)	[2]
Nuclear fuel	621	[2]
Accumulated amortization of nuclear fuel	(502)	[2]
Plant under construction	$ 116	[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	$ 576	[2]
Accumulated depreciation	(214)	[2]
Nuclear fuel	0	[2]
Accumulated amortization of nuclear fuel	0	[2]
Plant under construction	$ 16	[2]
[1]	Unit jointly owned by Dominion.
[2]	Units jointly owned by Virginia Power.

Property, Plant and Equipment94

Property, Plant and Equipment (Narrative) (Details) - Dominion Gas Holdings, LLC a in Thousands, $ in Millions	1 Months Ended				3 Months Ended		12 Months Ended
	Sep. 30, 2015USD ($)aField	Mar. 31, 2015USD ($)aNatural_Gas_ProducerField	Nov. 30, 2014USD ($)aField	Dec. 31, 2013USD ($)aNatural_Gas_Producer	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)aField	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)a
Property, Plant and Equipment [Line Items]
E&P properties being amortized and other					$ 136		$ 136	$ 140
Appalachian Exploration and Production Properties [Member]
Property, Plant and Equipment [Line Items]
E&P properties being amortized and other					14		14
Appalachian Exploration and Production Properties [Member] | Other operations and maintenance expense
Property, Plant and Equipment [Line Items]
Ceiling test impairment charge							16
Ceiling test impairment charge, net of tax							10
Oil and Gas Properties
Property, Plant and Equipment [Line Items]
After tax gain on sale					43	$ 29
Oil and Gas Properties | Marcellus Shale
Property, Plant and Equipment [Line Items]
Number of natural gas producers | Natural_Gas_Producer				2
Acres of development rights | a		11	24	100					100
Amount of consideration			$ 120	$ 200					$ 200
Period for payments related to conveyance of natural gas storage fields			4 years	9 years
Proceeds from assignment of Shale Development Rights		$ 27	$ 60					16	100
Total deferred revenue								$ 85
Number of natural gas storage fields | Field		1	1
Number of acres included in initial conveyance | a			12
Oil and Gas Properties | Marcellus Shale | Amended Agreement to Extend Conveyance of Development Rights
Property, Plant and Equipment [Line Items]
Number of natural gas producers | Natural_Gas_Producer		1
Acres of development rights | a		9
Period for payments related to conveyance of natural gas storage fields		2 years
Total deferred revenue					$ 37		$ 37
Oil and Gas Properties | Marcellus Shale | Other operations and maintenance expense
Property, Plant and Equipment [Line Items]
Gain from sale		$ 27	$ 60						20
After tax gain on sale		16	$ 36						$ 12
Oil and Gas Properties | Marcellus Shale | Other operations and maintenance expense | Amended Agreement to Extend Conveyance of Development Rights
Property, Plant and Equipment [Line Items]
Revenue recognized		43
Revenue recognized net of tax		$ 27
Oil and Gas Properties | Utica and Point Pleasant Shale
Property, Plant and Equipment [Line Items]
Acres of development rights | a	16					16
Amount of consideration	$ 52					$ 52
Proceeds from assignment of Shale Development Rights	$ 52
Number of natural gas storage fields | Field	1					1
Oil and Gas Properties | Utica and Point Pleasant Shale | Other operations and maintenance expense
Property, Plant and Equipment [Line Items]
Gain from sale	$ 52
After tax gain on sale	$ 29

Goodwill and Intangible Asset95

Goodwill and Intangible Assets (Goodwill) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	$ 3,044	$ 3,086
Asset disposition adjustment			(42)
DCG acquisition		250
Goodwill, Ending Balance	[1]	3,294	3,044
Operating Segments | Dominion Generation
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1],[2]	1,422	1,454
Asset disposition adjustment	[3]		(32)
DCG acquisition	[2]	0
Goodwill, Ending Balance	[1]	1,422	1,422	[2]
Operating Segments | Dominion Energy
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1],[2]	696	706
Asset disposition adjustment	[4]		(10)
DCG acquisition		250
Goodwill, Ending Balance	[1]	946	696	[2]
Operating Segments | DVP
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	926	926
Asset disposition adjustment			0
DCG acquisition		0
Goodwill, Ending Balance	[1]	926	926
Operating Segments | Corporate and Other
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1],[5]	0	0
Asset disposition adjustment	[5]		0
DCG acquisition	[5]	0
Goodwill, Ending Balance	[1],[5]	0	0
Dominion Gas Holdings, LLC
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	542	545
Asset disposition adjustment			(3)
No events affecting goodwill		0
Goodwill, Ending Balance	[1]	542	542
Dominion Gas Holdings, LLC | Operating Segments | Dominion Generation
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	0	0
Asset disposition adjustment			0
No events affecting goodwill		0
Goodwill, Ending Balance	[1]	0	0
Dominion Gas Holdings, LLC | Operating Segments | Dominion Energy
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	542	545
Asset disposition adjustment	[4]		(3)
No events affecting goodwill		0
Goodwill, Ending Balance	[1]	542	542
Dominion Gas Holdings, LLC | Operating Segments | DVP
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	0	0
Asset disposition adjustment			0
No events affecting goodwill		0
Goodwill, Ending Balance	[1]	0	0
Dominion Gas Holdings, LLC | Operating Segments | Corporate and Other
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1],[5]	0	0
Asset disposition adjustment	[5]		0
No events affecting goodwill	[5]	0
Goodwill, Ending Balance	[1],[5]	$ 0	$ 0
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	Recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.
[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.
[5]	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.

Goodwill and Intangible Asset96

Goodwill and Intangible Assets (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Line Items]
Amortization expense for intangible assets	$ 78	$ 71	$ 72
Acquisition of intangible assets	$ 78
Weighted-average amortization period (years)	8 years
Virginia Electric and Power Company
Goodwill [Line Items]
Amortization expense for intangible assets	$ 25	24	22
Acquisition of intangible assets	$ 34
Weighted-average amortization period (years)	6 years
Dominion Gas Holdings, LLC
Goodwill [Line Items]
Amortization expense for intangible assets	$ 18	$ 17	$ 16
Acquisition of intangible assets	$ 24
Weighted-average amortization period (years)	14 years

Goodwill and Intangible Asset97

Goodwill and Intangible Assets (Components of Intangible Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 942	$ 887
Accumulated Amortization	372	317
Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	301	286
Accumulated Amortization	88	81
Dominion Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	211	192
Accumulated Amortization	128	113
Software, licenses and other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	942	887
Accumulated Amortization	372	317
Software, licenses and other | Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	301	286
Accumulated Amortization	88	81
Software, licenses and other | Dominion Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	211	192
Accumulated Amortization	$ 128	$ 113

Goodwill and Intangible Asset98

Goodwill and Intangible Assets (Annual Amortization Expense of Intangible Assets) (Details) $ in Millions	Dec. 31, 2015USD ($)
Finite-Lived Intangible Assets [Line Items]
2,016	$ 79
2,017	68
2,018	57
2,019	47
2,020	35
Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
2,016	25
2,017	22
2,018	19
2,019	15
2,020	9
Dominion Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
2,016	18
2,017	15
2,018	14
2,019	13
2,020	$ 13

Regulatory Assets and Liabili99

Regulatory Assets and Liabilities (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets And Liabilities [Line Items]
Deferred cost of fuel used in electric generation	[1]	$ 111	$ 79
Deferred rate adjustment clause costs	[2]	90	124
Deferred nuclear refueling outage costs	[3]	75	44
Unrecovered gas costs	[4]	12	36
Other		63	64
Regulatory assets-current		351	347
Unrecognized pension and other postretirement benefit costs	[5]	1,015	1,050
Deferred rate adjustment clause costs	[2]	295	250
PJM transmission rates	[6]	192	0
Income taxes recoverable through future rates	[7]	126	133
Derivatives	[8]	110	101
Other		127	108
Regulatory assets-non-current		1,865	1,642
Total regulatory assets		2,216	1,989
PIPP, regulatory liabilities-current	[9]	46	71
Other		54	99
Regulatory liabilities-current	[10]	100	170
Provision for future cost of removal and AROs	[11]	1,120	1,072
Decommissioning trust	[12]	804	815
Deferred cost of fuel used in electric generation	[1]	97	6
Derivatives	[8]	79	0
Other		185	98
Regulatory liabilities-non-current		2,285	1,991
Total regulatory liabilities		$ 2,385	2,161
Maximum amortization period for deferred operation and maintenance costs		18 months
Virginia Electric and Power Company
Regulatory Assets And Liabilities [Line Items]
Deferred cost of fuel used in electric generation	[1]	$ 111	79
Deferred rate adjustment clause costs	[2]	80	117
Deferred nuclear refueling outage costs	[3]	75	44
Other		60	58
Regulatory assets-current		326	298
Deferred rate adjustment clause costs	[2]	213	179
PJM transmission rates	[6]	192	0
Income taxes recoverable through future rates	[7]	97	100
Derivatives	[8]	110	101
Other		55	59
Regulatory assets-non-current		667	439
Total regulatory assets		993	737
Other		35	90
Regulatory liabilities-current		35	90
Provision for future cost of removal	[11]	890	852
Decommissioning trust	[12]	804	815
Deferred cost of fuel used in electric generation	[1]	97	6
Derivatives	[8]	79	0
Other		59	10
Regulatory liabilities-non-current		1,929	1,683
Total regulatory liabilities		1,964	1,773
Dominion Gas Holdings, LLC
Regulatory Assets And Liabilities [Line Items]
Deferred rate adjustment clause costs	[2]	10	7
Unrecovered gas costs	[4]	11	29
Other		2	2
Regulatory assets-current		23	38
Unrecognized pension and other postretirement benefit costs	[5]	282	242
Deferred rate adjustment clause costs	[2]	82	71
Income taxes recoverable through future rates	[7]	20	24
Other		65	42
Regulatory assets-non-current		449	379
Total regulatory assets		472	417
PIPP, regulatory liabilities-current	[9]	46	71
Other		9	4
Regulatory liabilities-current		55	75
Provision for future cost of removal and AROs	[11]	170	172
Other		31	20
Regulatory liabilities-non-current		201	192
Total regulatory liabilities		$ 256	$ 267
[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.
[2]	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.
[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 and Dominion Gas' rate-regulated subsidiaries.
[6]	Reflects amount related to the PJM transmission cost allocation matter. See Note 13 for more information.
[7]	Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes.
[8]	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.
[9]	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 rate adjustment clause according to East Ohio tariff provisions. See Note 13 for more information.
[10]	Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.
[11]	Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.
[12]	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power’s utility nuclear generation stations, in excess of the related AROs.

Regulatory Assets and Liabil100

Regulatory Assets and Liabilities (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Regulatory Assets And Liabilities [Line Items]
Regulatory assets represented past expenditures not earning return	$ 131
Period expenditures expected to be recovered (years)	2 years
Virginia Electric and Power Company
Regulatory Assets And Liabilities [Line Items]
Regulatory assets represented past expenditures not earning return	$ 100
Dominion Gas Holdings, LLC
Regulatory Assets And Liabilities [Line Items]
Regulatory assets represented past expenditures not earning return	$ 29

Regulatory Matters (Narrative)

Regulatory Matters (Narrative) (Details) customer in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Feb. 29, 2016USD ($)kV

Jan. 31, 2016USD ($)

Dec. 31, 2015USD ($)

Nov. 30, 2015USD ($)kVmi

Oct. 31, 2015USD ($)FacilityMW

Sep. 30, 2015USD ($)

Aug. 31, 2015USD ($)Program

Jul. 31, 2015USD ($)

Jun. 30, 2015USD ($)

May. 31, 2015USD ($)kVmi

Apr. 30, 2015kV

Mar. 31, 2015USD ($)

Feb. 28, 2015USD ($)Test_PeriodMW

Jan. 31, 2015USD ($)MW

Oct. 31, 2014USD ($)

Apr. 30, 2014USD ($)

Nov. 30, 2013kVmi

Dec. 31, 2012USD ($)

May. 31, 2012USD ($)

Mar. 31, 2010USD ($)

Aug. 31, 2009kV

Apr. 30, 2007kV

Jun. 30, 2014USD ($)

Mar. 31, 2014USD ($)

Jun. 30, 2013USD ($)

Dec. 31, 2018USD ($)

Dec. 31, 2017USD ($)

Dec. 31, 2016USD ($)

Dec. 31, 2015USD ($)Power_Station

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)

Dec. 31, 2008

Dec. 31, 2007customer

Regulatory Matters [Line Items]

Regulatory asset

$ 2,216,000,000

$ 2,216,000,000

$ 1,989,000,000

Charge recognized

0

374,000,000

$ 0

Total amount of credit to customers

2,385,000,000

2,385,000,000

2,161,000,000

Plant construction and other property additions (including nuclear fuel)

$ 5,575,000,000

5,345,000,000

4,065,000,000

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

Facility operating capacity (kV) | kV

500

500

Regulatory asset

993,000,000

$ 993,000,000

737,000,000

Charge recognized

0

374,000,000

0

Total amount of credit to customers

1,964,000,000

1,964,000,000

1,773,000,000

Plant construction and other property additions (including nuclear fuel)

$ 2,474,000,000

$ 2,911,000,000

2,394,000,000

Charge recognized for cumulative recovery of costs, after tax

$ 191,000,000

Virginia Electric and Power Company | Virginia Regulation

Regulatory Matters [Line Items]

Approved fuel recovery amount

$ 1,600,000,000

Revenue increase (decrease)

(512,000,000)

Capacity of solar facility | MW

20

Virginia Electric and Power Company | Virginia Regulation | North Anna

Regulatory Matters [Line Items]

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 | North Anna | Legislation enacted | 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 | Surry Switching Station Transmission Line

Regulatory Matters [Line Items]

KV Line | kV

500

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

Regulatory Matters [Line Items]

Length of Transmission line | mi

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 | mi

20

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Surry to Skiffes Creek Transmission Line

Regulatory Matters [Line Items]

KV Line | kV

500

Virginia Electric and Power Company | Virginia Regulation | Poland Road Substation

Regulatory Matters [Line Items]

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Double Circuit Transmission Line between Loudoun-Brambleton Line and Poland Road Substation

Regulatory Matters [Line Items]

Total estimate cost

$ 55,000,000

Length of Transmission line | mi

4

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Loudoun- Brambleton Line

Regulatory Matters [Line Items]

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Transmission Line Near Gainesville Substation and Haymarket Substation

Regulatory Matters [Line Items]

Total estimate cost

$ 51,000,000

Length of Transmission line | mi

5

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Transmission Line between Remington and Gordonsville Substations

Regulatory Matters [Line Items]

Total estimate cost

$ 104,000,000

Length of Transmission line | mi

38

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Remington CT-Warrenton, Vint Hill-Wheeler, and Wheeler Gainesville Transmission Lines, and Vint Hill and Wheeler Switching Stations | Subsequent Event | Scenario, Forecast

Regulatory Matters [Line Items]

Total estimate cost

$ 105,000,000

Virginia Electric and Power Company | Virginia Regulation | Remington CT Warrenton Double Circuit Transmission Line | Subsequent Event | Scenario, Forecast

Regulatory Matters [Line Items]

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Vint Hill-Wheeler and Wheeler Gainesville Lines | Subsequent Event | Scenario, Forecast

Regulatory Matters [Line Items]

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Vint Hill and Wheeler Switching Stations | Subsequent Event | Scenario, Forecast

Regulatory Matters [Line Items]

KV Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | February 2015 Regulation Act Legislation

Regulatory Matters [Line Items]

Number of test periods | Test_Period

5

Virginia Electric and Power Company | Virginia Regulation | February 2015 Regulation Act Legislation | Deferred Fuel Costs

Regulatory Matters [Line Items]

Write off of prior period deferred fuel costs

$ 85,000,000

MW Capacity | MW

500

Virginia Electric and Power Company | Virginia Regulation | Virginia Commission 2015 Biennial Review

Regulatory Matters [Line Items]

Approved ROE

10.00%

Earned ROE percentage

10.89%

ROE above authorized ROE (basis points)

0.70%

Duration excess earnings will be credited to customers

6 months

Period after Biennial Review Order

60 days

Virginia Electric and Power Company | Virginia Regulation | Virginia Commission 2015 Biennial Review | Revenue Subject to Refund

Regulatory Matters [Line Items]

Total amount of credit to customers

$ 20,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider US-1 | Solar Development Project

Regulatory Matters [Line Items]

Total estimate cost

$ 47,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider US-2 | Solar Development Project

Regulatory Matters [Line Items]

Capacity of solar facility | MW

56

Total estimate cost

$ 130,000,000

Number of solar facilities | Facility

3

Virginia Electric and Power Company | Virginia Regulation | Rider T1

Regulatory Matters [Line Items]

Proposed revenue requirement

$ 668,000,000

Increase (decrease) in revenue requirement over the prior year

130,000,000

Amount of proposed deferred revenue requirement

$ 96,000,000

Percentage reduction in rate impact on residential customers

50.00%

Duration of rate impact on residential customers

1 year

Virginia Electric and Power Company | Virginia Regulation | Rider S

Regulatory Matters [Line Items]

Proposed revenue requirement

$ 250,000,000

Increase (decrease) in revenue requirement over the prior year

5,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider W

Regulatory Matters [Line Items]

Proposed revenue requirement

118,000,000

Increase (decrease) in revenue requirement over the prior year

(17,000,000)

Virginia Electric and Power Company | Virginia Regulation | Rider R

Regulatory Matters [Line Items]

Proposed revenue requirement

74,000,000

Increase (decrease) in revenue requirement over the prior year

(10,000,000)

Virginia Electric and Power Company | Virginia Regulation | Rider B

Regulatory Matters [Line Items]

Proposed revenue requirement

30,000,000

Increase (decrease) in revenue requirement over the prior year

$ 21,000,000

Number of power stations converted to biomass | Power_Station

3

Virginia Electric and Power Company | Virginia Regulation | Rider U

Regulatory Matters [Line Items]

Proposed revenue requirement

24,000,000

$ 28,000,000

Amount of proposed deferred revenue requirement

$ 24,000,000

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

Regulatory Matters [Line Items]

Proposed revenue requirement

$ 50,000,000

Number of new energy efficiency programs | Program

2

Period for cost cap

5 years

Cost cap amount

$ 51,000,000

Extension period for cost cap

5 years

Virginia Electric and Power Company | Virginia Regulation | Rider BW

Regulatory Matters [Line Items]

Proposed revenue requirement

$ 156,000,000

Increase (decrease) in revenue requirement over the prior year

45,000,000

Virginia Electric and Power Company | Virginia Regulation | Rider GV

Regulatory Matters [Line Items]

Proposed revenue requirement

$ 42,000,000

Virginia Electric and Power Company | North Carolina Regulation

Regulatory Matters [Line Items]

Approved ROE

10.20%

Revenue increase (decrease)

$ 22,000,000

Increase (decrease) in revenue requirement over the prior year

$ (11,000,000)

Cost cap amount

$ 17,000,000

Percentage of deferred fuel balance

50.00%

Virginia Electric and Power Company | North Carolina Regulation | Annual Non- Fuel Base Revenues

Regulatory Matters [Line Items]

Revenue increase (decrease)

36,000,000

Virginia Electric and Power Company | North Carolina Regulation | Annual Base Fuel Revenues

Regulatory Matters [Line Items]

Revenue increase (decrease)

$ (14,000,000)

Virginia Electric and Power Company | FERC | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Settled Litigation | Legislation enacted

Regulatory Matters [Line Items]

Settlement amount

$ 200,000,000

Settlement payment period

10 years

Virginia Electric and Power Company | FERC | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Settled Litigation | Legislation enacted | Regulatory Asset for contingent liability

Regulatory Matters [Line Items]

Regulatory asset

$ 192,000,000

$ 192,000,000

Virginia Electric and Power Company | FERC | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Settled Litigation | Legislation enacted | Other operations and maintenance expense

Regulatory Matters [Line Items]

Charge recognized

8,000,000

Virginia Electric and Power Company | FERC | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Settled Litigation | Legislation enacted | Other Deferred Credits and Other Liabilities

Regulatory Matters [Line Items]

Amount of accrued liability

$ 200,000,000

$ 200,000,000

East Ohio | Ohio Regulation | PIR Program

Regulatory Matters [Line Items]

Proposed revenue requirement

$ 108,000,000

Percentage replacement of pipeline system

25.00%

Extension period for PIR program

5 years

Estimated cost of project

$ 200,000,000

Annual percentage increase in capital investment

3.00%

Total estimated cost

829,000,000

$ 155,000,000

East Ohio | Ohio Regulation | PIR Program | Scenario, Forecast

Regulatory Matters [Line Items]

Increase in PIR investment

$ 20,000,000

$ 20,000,000

East Ohio | Ohio Regulation | AMR Program

Regulatory Matters [Line Items]

Proposed revenue requirement

$ 8,000,000

Number of customers with automated meter reading technology | customer

1.2

East Ohio | Ohio Regulation | PIPP Plus Program

Regulatory Matters [Line Items]

Refund of overrecovery of accumulated arrearages

57,000,000

Recovery of projected deferred program costs

35,000,000

East Ohio | Ohio Regulation | UEX Rider

Regulatory Matters [Line Items]

Elimination of over-recovered balance of accumulated bad debt expense

14,000,000

Prospective bad debt expense recovered

$ 20,000,000

East Ohio | Ohio Regulation | PSMP

Regulatory Matters [Line Items]

Estimated cost of project

15,000,000

Cove Point | FERC | St Charles Transportation Project

Regulatory Matters [Line Items]

Expected cost of project

30,000,000

Cove Point | FERC | Keys Energy Project

Regulatory Matters [Line Items]

Expected cost of project

$ 40,000,000

Hope Gas Inc | West Virginia Regulation | PREP

Regulatory Matters [Line Items]

Extension period for PIR program

5 years

Estimated cost of project

$ 158,000,000

Hope Gas Inc | West Virginia Regulation | PREP | Scenario, Forecast

Regulatory Matters [Line Items]

Increase in PIR investment

$ 24,000,000

Hope Gas Inc | West Virginia Regulation | Subsequent Event | PREP

Regulatory Matters [Line Items]

Revenue increase (decrease)

$ 20,000,000

DCG | FERC | Edgemoor Project

Regulatory Matters [Line Items]

Expected cost of project

$ 35,000,000

DCG | FERC | Columbia to Eastover Project

Regulatory Matters [Line Items]

Expected cost of project

$ 35,000,000

Asset Retirement Obligations (N

Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations [Line Items]
Nuclear decommissioning trust funds	$ 4,183	$ 4,196
Virginia Electric and Power Company
Asset Retirement Obligations [Line Items]
Nuclear decommissioning trust funds	$ 1,945	$ 1,930

Asset Retirement Obligations (C

Asset Retirement Obligations (Changes to AROs) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance		$ 1,714	[1]	$ 1,578
Obligations incurred during the period		315	[2]	40
Obligations settled during the period		(106)		(82)
Revisions in estimated cash flows		88	[2]	102	[3]
Accretion		93		81
Other		(1)		(5)
AROs , Ending balance	[1]	2,103		1,714
Asset retirement obligations, non current		1,887		1,633
Current Liabilities
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, current		216		81
Virginia Electric and Power Company
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance		855		689
Obligations incurred during the period		289	[2]	28
Obligations settled during the period		(39)		(1)
Revisions in estimated cash flows		92	[2]	108	[3]
Accretion		50		37
Other				(6)
AROs , Ending balance		1,247		855
Asset retirement obligation, current		143		7
Asset retirement obligations, non current		1,104		848
Dominion Gas Holdings, LLC
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance		147	[4]	137
Obligations incurred during the period		5		2
Obligations settled during the period		(6)		(8)
Revisions in estimated cash flows		(5)
Accretion		9		8
Other		(1)		8
AROs , Ending balance	[4]	149		147
Dominion Gas Holdings, LLC | Other Deferred Credits and Other Liabilities
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligations, non current		$ 137		$ 140
[1]	Includes $81 million and $216 million reported in other current liabilities at December 31, 2014, and 2015, respectively.
[2]	Primarily reflects future ash pond and landfill closure costs at certain utility generation facilities. See Note 22 for further information.
[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 $140 million and $137 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2014 and 2015, respectively.

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) $ in Millions	1 Months Ended		12 Months Ended
	Sep. 30, 2014	Aug. 31, 2013USD ($)	Dec. 31, 2015USD ($)generatorMW	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Variable Interest Entity [Line Items]
Acquisition of Juniper noncontrolling interest in Fairless			$ 0	$ 0	$ 923
Dominion Gas Holdings, LLC
Variable Interest Entity [Line Items]
Shared services purchased			$ 115	106	115
Virginia Electric and Power Company
Variable Interest Entity [Line Items]
Number of non utility generators | generator			5
Number of expired non-utility generators | generator			2
Aggregate generation capacity from long-term power and capacity contracts (MW) | MW			418
Remaining purchase commitments			$ 439
Payment for electric capacity			200	223	217
Payment for electric energy			83	138	98
Shared services purchased			$ 318	$ 335	$ 331
Juniper
Variable Interest Entity [Line Items]
Acquisition of Juniper noncontrolling interest in Fairless		$ 923
Variable Interest Entity, Not Primary Beneficiary | Iroquois | Dominion Midstream Partners, LP
Variable Interest Entity [Line Items]
Initial membership interest percentage			25.93%
Variable Interest Entity, Not Primary Beneficiary | Iroquois | Dominion Gas Holdings, LLC
Variable Interest Entity [Line Items]
Initial membership interest percentage			24.72%
Variable Interest Entity, Not Primary Beneficiary | Distribution | Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline
Variable Interest Entity [Line Items]
Initial membership interest percentage	45.00%

Short-Term Debt And Credit A105

Short-Term Debt And Credit Agreements (Commercial Paper, Bank Loans, and Letters of Credit Outstanding, as well as Capacity Available Under Credit Facilities (Details)		1 Months Ended
		Jan. 31, 2016USD ($)	Dec. 31, 2015USD ($)Facility		Dec. 31, 2014USD ($)
Short term Debt [Line Items]
Facility Limit	[1]		$ 4,500,000,000		$ 4,500,000,000
Outstanding Commercial Paper	[2]		3,509,000,000		2,775,000,000
Outstanding Letters of Credit			59,000,000		48,000,000
Facility Capacity Available			$ 932,000,000		1,677,000,000
Weighted-average interest rates	[3],[4]		2.38%
Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit	[5]		$ 4,500,000,000		4,500,000,000
Outstanding Commercial Paper	[6]		1,656,000,000		1,361,000,000
Outstanding Letters of Credit			$ 0		0
Weighted-average interest rates	[4]		5.24%
Number of joint revolving credit facilities | Facility			2
Credit facility			$ 120,000,000
Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Facility Limit	[7]		1,500,000,000		1,500,000,000
Outstanding Commercial Paper			391,000,000	[8]	0
Outstanding Letters of Credit			$ 0		0
Weighted-average interest rates	[4]		1.05%
Number of joint revolving credit facilities | Facility			2
Line of Credit | Virginia Electric and Power Company
Short term Debt [Line Items]
Credit facility, to support letters of credit			$ 120,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Virginia Electric and Power Company
Short term Debt [Line Items]
Credit facility, to support letters of credit			1,750,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Facility Limit					$ 1,500,000,000
Credit facility, to support letters of credit			500,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Letter of Credit
Short term Debt [Line Items]
Credit facility, to support letters of credit			2,000,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Letter of Credit | Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit			2,000,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Letter of Credit | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Facility Limit			1,500,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Line of Credit
Short term Debt [Line Items]
Facility Limit			4,000,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Line of Credit | Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit			$ 4,000,000,000
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Commercial Paper
Short term Debt [Line Items]
Weighted-average interest rates			0.62%		0.38%
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Commercial Paper | Virginia Electric and Power Company
Short term Debt [Line Items]
Weighted-average interest rates			0.60%		0.36%
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Commercial Paper | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Weighted-average interest rates			0.63%
Credit Facility 4 Billion
Short term Debt [Line Items]
Facility Limit	[1]		$ 4,000,000,000	[9]	$ 4,000,000,000
Outstanding Commercial Paper	[1]		3,353,000,000	[9]	2,664,000,000
Outstanding Letters of Credit	[1]		0	[9]	0
Facility Capacity Available	[1]		647,000,000	[9]	1,336,000,000
Credit Facility 4 Billion | Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit	[5]		4,000,000,000	[10]	4,000,000,000
Outstanding Commercial Paper	[5]		1,500,000,000	[10]	1,250,000,000
Outstanding Letters of Credit	[5]		0	[10]	0
Credit Facility 4 Billion | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Facility Limit	[7]		1,000,000,000		1,000,000,000
Outstanding Commercial Paper	[7]		391,000,000		0
Outstanding Letters of Credit	[7]		0		0
Credit Facility 500 million
Short term Debt [Line Items]
Facility Limit	[1]		500,000,000		500,000,000
Outstanding Commercial Paper	[1]		156,000,000		111,000,000
Outstanding Letters of Credit	[1]		59,000,000		48,000,000
Facility Capacity Available	[1]		285,000,000		341,000,000
Credit Facility 500 million | Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit	[5]		500,000,000		500,000,000
Outstanding Commercial Paper	[5]		156,000,000		111,000,000
Outstanding Letters of Credit	[5]		0		0
Credit Facility 500 million | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Facility Limit	[7]		500,000,000		500,000,000
Outstanding Commercial Paper	[7]		0		0
Outstanding Letters of Credit	[7]		0		$ 0
Tax-Exempt Financings | Virginia Electric and Power Company
Short term Debt [Line Items]
Variable rate tax-exempt financings			$ 119,000,000
Subsequent Event | Revolving Credit Facility
Short term Debt [Line Items]
Increase in revolving credit facility limits		$ 1,000,000,000
Subsequent Event | Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Line of Credit
Short term Debt [Line Items]
Facility Limit		5,000,000,000
Subsequent Event | Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Line of Credit | Virginia Electric and Power Company
Short term Debt [Line Items]
Facility Limit		5,000,000,000
Subsequent Event | Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Line of Credit | Dominion Gas Holdings, LLC
Short term Debt [Line Items]
Credit facility, to support letters of credit		$ 1,000,000,000
[1]	These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to a combined $2.0 billion of letters of credit.
[2]	The weighted-average interest rates of the outstanding commercial paper supported by Dominion’s credit facilities were 0.62% and 0.38% at December 31, 2015 and 2014, respectively.
[3]	Includes $4 million for fair value hedge valuation in 2014. Excludes $100 million of variable rate short-term notes scheduled to mature in May 2016 that were purchased and cancelled using the proceeds from the February 2016 issuance of senior notes that mature in 2018.
[4]	Represents weighted-average coupon rates for debt outstanding as of December 31, 2015.
[5]	The full amount of the facilities is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion and Dominion Gas. Sub-limits for Virginia Power are set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2015, the sub-limit for Virginia Power was an aggregate $1.75 billion. If Virginia Power has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion. These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $2.0 billion (or the sub-limit, whichever is less) of letters of credit.
[6]	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.60% and 0.36% at December 31, 2015 and 2014, respectively.
[7]	A maximum of a combined $1.5 billion of the facilities is available to Dominion Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion and Virginia Power. Sub-limits for Dominion Gas are set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2015, the sub-limit for Dominion Gas was an aggregate $500 million. In January 2016, the aggregate sub-limit for Dominion Gas was increased to $1.0 billion. If Dominion Gas has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion. These credit facilities mature in April 2019, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (or the sub-limit, whichever is less) of letters of credit.
[8]	The weighted-average interest rate of the outstanding commercial paper supported by these credit facilities was 0.63% at December 31, 2015.
[9]	In January 2016, this facility limit was increased from $4.0 billion to $5.0 billion.
[10]	In January 2016, this facility limit was increased from $4.0 billion to $5.0 billion.

Long-Term Debt (Total Long Term

Long-Term Debt (Total Long Term Debt) (Details) - USD ($)		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[1],[2]	2.38%
Total principal, including VIE		$ 25,473,000,000	$ 23,200,000,000
Securities due within one year, including VIE	[1]	(1,826,000,000)	(1,375,000,000)
Unamortized discount and premium, net		(38,000,000)	(39,000,000)
Total long term debt, including VIE		23,616,000,000	21,805,000,000
Fair value hedge valuation	[3]	7,000,000	19,000,000
Unamortized premium and discount			4,000,000
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		2,033
Redemption percentage of principal and accrued interest		100.00%
Variable Rate Short Term Notes Maturing in May 2016 | Variable rate short-term notes
Debt Instrument [Line Items]
Principal amount of notes		$ 100,000,000
Senior Notes | Variable rates, due 2015 and 2016
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2]	1.11%
Total principal, including VIE		$ 600,000,000	400,000,000
Senior Notes | 1.25% to 6.4%, due 2015 to 2019
Debt Instrument [Line Items]
Interest rate, minimum		1.25%
Interest rate, maximum		6.40%
2014 Weighted- average Coupon	[2]	3.05%
Total principal, including VIE		$ 3,400,000,000	3,150,000,000
Senior Notes | 2.75% to 7.0%, due 2021 to 2044
Debt Instrument [Line Items]
Interest rate, minimum		2.75%
Interest rate, maximum		7.00%
2014 Weighted- average Coupon	[2],[4]	4.80%
Total principal, including VIE	[4]	$ 5,099,000,000	4,449,000,000
Senior Notes | 6.8% and 6.875%, due 2026 and 2027
Debt Instrument [Line Items]
Interest rate, minimum		6.80%
Interest rate, maximum		6.875%
2014 Weighted- average Coupon	[2],[5]	6.81%
Total principal, including VIE	[5]	$ 89,000,000	89,000,000
Tax-Exempt Financings | Tax-Exempt Financing, variable rate, due 2041
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2]	1.16%
Total principal, including VIE		$ 75,000,000	75,000,000
Tax-Exempt Financings | Tax-Exempt Financing, 2.375%, due 2033
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2]	2.38%
Total principal, including VIE		$ 27,000,000	27,000,000
RSN Annual Interest Rate		2.375%
Junior Subordinated Notes | Unsecured Junior Subordinated Notes Payable to Affiliated Trust, 8.4%, due 2031
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2]	8.40%
Total principal, including VIE		$ 10,000,000	10,000,000
RSN Annual Interest Rate		8.40%
Junior Subordinated Notes | 5.75% and 7.5%, due 2054 and 2066
Debt Instrument [Line Items]
Interest rate, minimum		5.75%
Interest rate, maximum		7.50%
2014 Weighted- average Coupon	[2]	6.27%
Total principal, including VIE		$ 971,000,000	985,000,000
Junior Subordinated Notes | Enhanced Junior Subordinated Notes, variable rate, due 2066
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2]	2.90%
Total principal, including VIE		$ 377,000,000	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%
2014 Weighted- average Coupon	[2]	1.30%
Total principal, including VIE		$ 2,100,000,000	2,100,000,000
Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2]	1.05%
Total principal, including VIE		$ 3,300,000,000	2,600,000,000
Securities due within one year, including VIE		(400,000,000)
Unamortized discount and premium, net		(8,000,000)	(6,000,000)
Total long term debt, including VIE		$ 2,892,000,000	2,594,000,000
Dominion Gas Holdings, LLC | Senior Notes | 1.05% to 2.8%, due 2016 to 2020
Debt Instrument [Line Items]
Interest rate, minimum		1.05%
Interest rate, maximum		2.80%
2014 Weighted- average Coupon	[2]	2.26%
Total principal, including VIE		$ 1,550,000,000	850,000,000
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%
2014 Weighted- average Coupon	[2]	4.15%
Total principal, including VIE		$ 1,750,000,000	1,750,000,000
Virginia Electric and Power Company
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2]	5.24%
Total principal, including VIE		$ 9,425,000,000	8,935,000,000
Securities due within one year, including VIE		(476,000,000)	(211,000,000)
Unamortized discount and premium, net		0	2,000,000
Total long term debt, including VIE		8,949,000,000	8,726,000,000
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		8.625%
2014 Weighted- average Coupon	[2]	5.03%
Total principal, including VIE		$ 2,261,000,000	2,471,000,000
Virginia Electric and Power Company | Senior Notes | 2.75% to 8.875%, due 2022 to 2045
Debt Instrument [Line Items]
Interest rate, minimum		2.75%
Interest rate, maximum		8.875%
2014 Weighted- average Coupon	[2]	4.91%
Total principal, including VIE		$ 6,292,000,000	5,592,000,000
Virginia Electric and Power Company | Tax-Exempt Financings | Variable rates, due 2016 to 2041
Debt Instrument [Line Items]
2014 Weighted- average Coupon	[2],[6]	0.79%
Total principal, including VIE	[6]	$ 194,000,000	606,000,000
Virginia Electric and Power Company | Tax-Exempt Financings | 0.70% to 5.6%, due 2023 to 2041
Debt Instrument [Line Items]
Interest rate, minimum		0.70%
Interest rate, maximum		5.60%
2014 Weighted- average Coupon	[2],[6]	2.19%
Total principal, including VIE	[6]	$ 678,000,000	$ 266,000,000
[1]	Includes $4 million for fair value hedge valuation in 2014. Excludes $100 million of variable rate short-term notes scheduled to mature in May 2016 that were purchased and cancelled using the proceeds from the February 2016 issuance of senior notes that mature in 2018.
[2]	Represents weighted-average coupon rates for debt outstanding as of December 31, 2015.
[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 were 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 Dominion’s Consolidated Balance Sheets. The option to redeem the notes expired in June 2015. At December 31, 2015, the notes are included in long-term debt in Dominion’s 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.

Long-Term 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 ($)		Feb. 29, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
2,016			$ 1,926,000,000
2,017			1,429,000,000
2,018			1,850,000,000
2,019			2,550,000,000
2,020			1,700,000,000
Thereafter			16,018,000,000
Total			25,473,000,000
Variable rate short-term notes | Variable Rate Short Term Notes Maturing in May 2016
Debt Instrument [Line Items]
Principal amount of notes			100,000,000
Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
2,016			400,000,000
2,017			0
2,018			0
2,019			450,000,000
2,020			700,000,000
Thereafter			1,750,000,000
Total			3,300,000,000
Virginia Electric and Power Company
Debt Instrument [Line Items]
2,016			476,000,000
2,017			679,000,000
2,018			850,000,000
2,019			350,000,000
2,020			0
Thereafter			7,070,000,000
Total			$ 9,425,000,000
2,016
Debt Instrument [Line Items]
Weighted-average Coupon			2.31%
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%
2,017
Debt Instrument [Line Items]
Weighted-average Coupon			3.28%
2017 | Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Weighted-average Coupon
2017 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon			5.44%
2,018
Debt Instrument [Line Items]
Weighted-average Coupon			4.16%
2018 | Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Weighted-average Coupon
2018 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon			4.17%
2,019
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%
2,020
Debt Instrument [Line Items]
Weighted-average Coupon			2.04%
2020 | Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Weighted-average Coupon			2.80%
2020 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average Coupon			0.00%
Thereafter
Debt Instrument [Line Items]
Weighted-average Coupon			4.54%
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			4.59%
Unsecured Senior Notes
Debt Instrument [Line Items]
2,016	[1]		$ 1,907,000,000
2,017	[1]		1,354,000,000
2,018	[1]		1,850,000,000
2,019	[1]		2,000,000,000
2,020	[1]		700,000,000
Thereafter	[1]		13,230,000,000
Total	[1]		21,041,000,000
Tax-Exempt Financings
Debt Instrument [Line Items]
2,016			19,000,000
2,017			75,000,000
2,018			0
2,019			0
2,020			0
Thereafter			880,000,000
Total			974,000,000
Unsecured Junior Subordinated Notes Payable to Affiliated Trusts
Debt Instrument [Line Items]
2,016			0
2,017			0
2,018			0
2,019			0
2,020			0
Thereafter			10,000,000
Total			10,000,000
Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
2,016			0
2,017			0
2,018			0
2,019			0
2,020			0
Thereafter			1,348,000,000
Total			1,348,000,000
Remarketable Subordinated Notes
Debt Instrument [Line Items]
2,016			0
2,017			0
2,018			0
2,019			550,000,000
2,020			1,000,000,000
Thereafter			550,000,000
Total			$ 2,100,000,000
Subsequent Event | Variable rate short-term notes | Variable Rate Short Term Notes Maturing in May 2016
Debt Instrument [Line Items]
Amount purchased and cancelled		$ 100,000,000
[1]	In February 2016, Dominion purchased and cancelled $100 million of variable rate short-term notes that would have otherwise matured in May 2016 using the proceeds from the February 2016 issuance of senior notes that mature in 2018. As a result, at December 31, 2015, $100 million of the notes were included in long-term debt in the Consolidated Balance Sheets.

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details)

Oct. 01, 2024

Jul. 31, 2017shares

Jul. 31, 2016shares

Apr. 30, 2016shares

Dec. 31, 2014USD ($)

Oct. 31, 2014USD ($)

Jul. 31, 2014USD ($)

Jun. 30, 2013USD ($)

Jan. 31, 2013USD ($)$ / sharesshares

Sep. 30, 2011

Dec. 31, 2015USD ($)senior_note$ / sharesshares

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)

Mar. 31, 2016USD ($)

Feb. 29, 2016USD ($)

Jan. 31, 2016USD ($)

Nov. 30, 2014USD ($)

Jul. 01, 2014

Jun. 30, 2009USD ($)

Sep. 30, 2006USD ($)

Jul. 01, 2006

Jun. 30, 2006USD ($)

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 25,473,000,000

Make-whole premium amount

$ 0

$ 284,000,000

$ 0

Shares issued in excess of principal amounts related to converted securities

28,000,000

Noncontrolling interest, ownership percentage by parent

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 | shares

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 | $ / shares

$ 1,019.58

Period of deferral

10 years

Period for consideration of proceeds (days)

180 days

365 days

Interest in RSN issued by Dominion (percentage)

5.00%

Scenario, Forecast | Minimum

Debt Instrument [Line Items]

Shares to be issued under purchase contracts | shares

11,500,000

8,500,000

8,500,000

Scenario, Forecast | Maximum

Debt Instrument [Line Items]

Shares to be issued under purchase contracts | shares

14,400,000

10,000,000

10,000,000

Common Stock

Debt Instrument [Line Items]

Purchase price to be paid under stock purchase contracts | $ / shares

$ 50

Shares reserved and available for issuance | shares

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

6.125%

6.375%

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)

2.825%

7.50%

Aggregate redemption price paid

$ 14,000,000

Junior subordinated notes

$ 300,000,000

June 2006 hybrids | Scenario, Forecast

Debt Instrument [Line Items]

Aggregate redemption price paid

$ 37,000,000

September 2006 hybrids

Debt Instrument [Line Items]

Interest rate (percentage)

2.30%

Aggregate redemption price paid

3,000,000

Junior subordinated notes

$ 500,000,000

September 2006 hybrids | Scenario, Forecast

Debt Instrument [Line Items]

Aggregate redemption price paid

$ 2,000,000

June 2009 hybrids

Debt Instrument [Line Items]

Interest rate (percentage)

8.375%

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

Virginia Electric and Power Company

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 9,425,000,000

Senior Notes

Debt Instrument [Line Items]

Number of outstanding series of senior notes | senior_note

5

Aggregate outstanding principal amount

$ 1,900,000,000

Aggregate redemption price paid

2,200,000,000

Make-whole premium amount

$ 263,000,000

Interest charges

284,000,000

Senior Notes | Senior Notes Due in 2026 | Subsequent Event | Virginia Electric and Power Company

Debt Instrument [Line Items]

Principal amount of notes

$ 750,000,000

Interest rate (percentage)

3.15%

Senior Notes | Senior Notes Due in 2018 | Subsequent Event | Virginia Electric and Power Company | Scenario, Forecast

Debt Instrument [Line Items]

Principal amount of notes

$ 500,000,000

Interest rate (percentage)

2.125%

Convertible Debt

Debt Instrument [Line Items]

Outstanding contingent convertible senior notes

0

0

$ 22,000,000

Shares issued in excess of principal amounts related to converted securities

$ 26,000,000

Unsecured Junior Subordinated Notes Payable to Affiliated Trusts

Debt Instrument [Line Items]

Aggregate outstanding principal amount

10,000,000

Interest charges

$ 1,000,000

$ 1,000,000

$ 1,000,000

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

Debt Instrument [Line Items]

Principal amount of notes

$ 685,000,000

Interest rate (percentage)

5.75%

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

Debt Instrument [Line Items]

Spread on variable rate

3.057%

Long-Term Debt Long Term Debt (

Long-Term Debt Long Term Debt (Schedule of Equity Units) (Details) - USD ($) shares in Millions, $ in Millions		Jul. 01, 2014	Jun. 07, 2013	Dec. 31, 2015	Dec. 31, 2014
Capital Unit [Line Items]
Stock Purchase Contract Liability	[1]			$ 115	$ 216
Total payments				$ 101	$ 66
Capital Unit, Class A
Capital Unit [Line Items]
Units Issued		20	11
Total Net Proceeds		$ 982	$ 533.5
Stock Purchase Contract Annual Rate		4.875%	5.055%
Stock Purchase Contract Liability	[1]	$ 142.8	$ 76.7
Capital Unit, Class A | Remarketable Subordinated Notes
Capital Unit [Line Items]
Total Long-term Debt		$ 1,000	$ 550
RSN Annual Interest Rate		1.50%	1.07%
Capital Unit, Class B
Capital Unit [Line Items]
Units Issued			11
Total Net Proceeds			$ 553.5
Stock Purchase Contract Annual Rate			4.82%
Stock Purchase Contract Liability	[1]		$ 79.3
Capital Unit, Class B | Remarketable Subordinated Notes
Capital Unit [Line Items]
Total Long-term Debt			$ 550
RSN Annual Interest Rate			1.18%
[1]	Payments of $101 million and $66 million were made in 2015 and 2014, respectively. The stock purchase contract liability was $115 million and $216 million at December 31, 2015 and 2014, respectively.

Preferred Stock (Narrative) (De

Preferred Stock (Narrative) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015
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
Amount each share is entitled to receive		$ 100
Amount of all outstanding series of preferred stock redeemed	2,590,000

Equity (Narrative) (Details)

Equity (Narrative) (Details) shares in Thousands

Mar. 15, 2016USD ($)Performance_Metric

Sep. 30, 2013

May. 31, 2015USD ($)shares

Jan. 31, 2015shares

Dec. 31, 2014USD ($)Agreementshares

Mar. 31, 2016USD ($)shares

Dec. 31, 2015USD ($)shares

Jun. 30, 2015USD ($)shares

Dec. 31, 2015USD ($)Performance_Metricshares

Dec. 31, 2014USD ($)Performance_Metricshares

Dec. 31, 2013USD ($)Performance_Metric

Dec. 31, 2007

Mar. 15, 2017USD ($)

Feb. 23, 2016USD ($)

Sep. 30, 2015USD ($)

Feb. 28, 2015USD ($)

Jan. 31, 2014USD ($)

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

Cash proceeds

$ 786,000,000

$ 205,000,000

$ 278,000,000

Common stock, shares outstanding | shares

585,000

596,000

596,000

585,000

Compensation cost related to stock-based compensation

$ 39,000,000

$ 39,000,000

31,000,000

Tax benefit from stock awards and stock options exercised

14,000,000

14,000,000

11,000,000

Tax benefits from the vesting of restricted stock awards (less than $1 million in 2014 and 2013)

$ 3,000,000

1,000,000

1,000,000

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 | shares

50,000

50,000

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 | shares

25,000

25,000

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

2 years

Fair value of restricted stock awards that vested

$ 37,000,000

$ 19,000,000

$ 20,000,000

Goal-Based Stock

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

Vesting period

3 years

Number of performance metrics | Performance_Metric

2

Performance metrics period

2 years

Shares issued minimum percentage

0.00%

Shares issued maximum percentage

200.00%

Targeted shares expected to be issued | shares

24

24

Number of shares converted to one class to another | shares

10

Dominion Gas Holdings, LLC

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

Percentage of limited liability membership interests

100.00%

Dominion Midstream Limited Partner Common Unit Purchase Program | Limited partner interest in Dominion Midstream | Dominion Midstream Partners, LP

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

Authorized purchase amount (up to $50 million)

$ 50,000,000

Period to acquire common units

12 months

Number of common units purchased | shares

887

Value of common units purchased

$ 25,000,000

Dominion Midstream Limited Partner Common Unit Purchase Program | Limited partner interest in Dominion Midstream | Dominion Midstream Partners, LP | Subsequent Event

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

Remaining value of common units authorized to purchase under program

$ 15,000,000

Dominion Midstream Limited Partner Common Unit Purchase Program | Limited partner interest in Dominion Midstream | Dominion Midstream Partners, LP | Subsequent Event | Scenario, Forecast

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

Number of common units purchased | shares

377

Value of common units purchased

$ 10,000,000

Various Programs

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

Cash proceeds

$ 783,000,000

Number of shares issued | shares

11,000

Common stock, shares outstanding | shares

596,000

596,000

Employee Stock

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

Cash proceeds received from issuance of shares through Dominion Direct and employee savings plans

$ 284,000,000

Number of shares issued through Dominion Direct and employee savings plans | shares

4,100

Shelf Registration for Sale of Common Stock through At-the-market Program

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

Cash proceeds

$ 297,000,000

Number of shares issued | shares

4,000

Number of sales agency agreements | Agreement

4

Aggregate amount of common stock in which Dominion may offer under sales agency agreements

$ 500,000,000

Net fees and commissions paid

$ 3,000,000

Common stock reserved for issuance in connection with stock purchase contracts

$ 200,000,000

$ 200,000,000

Registered Underwritten Public Offering

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

Cash proceeds

$ 202,000,000

Number of shares issued | shares

2,800

Cash-Based Performance Grant | Officer

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 2012 Awards | Officer

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

Number of performance metrics | Performance_Metric

2

Expected award under grant

$ 8,000,000

$ 12,000,000

February 2013 Awards | Officer

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

Number of performance metrics | Performance_Metric

2

Expected award under grant

$ 14,000,000

$ 14,000,000

$ 20,000,000

February 2014 Awards | Officer

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

Liability accrued for award

10,000,000

$ 10,000,000

February 2014 Awards | Officer | Scenario, Forecast

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

Number of performance metrics | Performance_Metric

2

Expected award under grant

$ 10,000,000

February 2015 Cash Based Performance Grant | Officer

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

Number of performance metrics | Performance_Metric

2

Liability accrued for award

$ 7,000,000

$ 7,000,000

February 2015 Cash Based Performance Grant | Officer | Scenario, Forecast

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

Expected award under grant

$ 14,000,000

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net unrealized losses on derivatives-hedging activities, net of tax	$ (176)	$ (178)
Net unrealized gains on nuclear decommissioning trust funds, net of tax	504	548
Net unrecognized pension and other postretirement benefit costs, net of tax	(797)	(782)
Other comprehensive loss from equity method investees, net of tax	(5)	(4)
Total AOCI	(474)	(416)	$ (324)
Net unrealized gains on derivatives-hedging activities, tax	110	116
Net unrealized gains on nuclear decommissioning trust funds, tax	(281)	(333)
Net unrecognized pension and other postretirement benefit costs, tax	525	530
Other comprehensive loss from equity method investees, tax	4	3
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net unrealized losses on derivatives-hedging activities, net of tax	(7)	(7)
Net unrealized gains on nuclear decommissioning trust funds, net of tax	47	57
Total AOCI	40	50	48
Net unrealized gains on derivatives-hedging activities, tax	4	4
Net unrecognized pension and other postretirement benefit costs, tax	(30)	(35)
Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net unrealized losses on derivatives-hedging activities, net of tax	(17)	(20)
Net unrealized gains on nuclear decommissioning trust funds, net of tax	(82)	(66)
Total AOCI	(99)	(86)	$ (58)
Net unrealized gains on derivatives-hedging activities, tax	10	11
Net unrecognized pension and other postretirement benefit costs, tax	$ 56	$ 46

Equity (Schedule of Components

Equity (Schedule of Components of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		$ (416)	$ (324)
Other comprehensive income before reclassifications: gains (losses)		49	(164)
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[1]	(107)	72
Other comprehensive income (loss)		(58)	(92)	$ 553
Ending balance		(474)	(416)	(324)
Deferred gains and losses on derivatives-hedging activities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		(178)	(288)
Other comprehensive income before reclassifications: gains (losses)		110	17
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[1]	(108)	93
Other comprehensive income (loss)		2	110
Ending balance		(176)	(178)	(288)
Unrealized gains and losses on investment securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		548	474
Other comprehensive income before reclassifications: gains (losses)		6	128
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[1]	(50)	(54)
Other comprehensive income (loss)		(44)	74
Ending balance		504	548	474
Unrecognized pension and other postretirement benefit costs
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		(782)	(510)
Other comprehensive income before reclassifications: gains (losses)		(66)	(305)
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[1]	51	33
Other comprehensive income (loss)		(15)	(272)
Ending balance		(797)	(782)	(510)
Other comprehensive loss from equity method investees
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		(4)	0
Other comprehensive income before reclassifications: gains (losses)		(1)	(4)
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[1]	0	0
Other comprehensive income (loss)		(1)	(4)
Ending balance		(5)	(4)	0
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		50	48
Other comprehensive income before reclassifications: gains (losses)		(5)	11
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[2]	(5)	(9)
Other comprehensive income (loss)		(10)	2	23
Ending balance		40	50	48
Virginia Electric and Power Company | Deferred gains and losses on derivatives-hedging activities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		(7)	0
Other comprehensive income before reclassifications: gains (losses)		(1)	(4)
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[2]	1	(3)
Other comprehensive income (loss)		0	(7)
Ending balance		(7)	(7)	0
Virginia Electric and Power Company | Unrealized gains and losses on investment securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		57	48
Other comprehensive income before reclassifications: gains (losses)		(4)	15
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[2]	(6)	(6)
Other comprehensive income (loss)		(10)	9
Ending balance		47	57	48
Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		(86)	(58)
Other comprehensive income before reclassifications: gains (losses)		(14)	(41)
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[3]	1	13
Other comprehensive income (loss)		(13)	(28)	82
Ending balance		(99)	(86)	(58)
Dominion Gas Holdings, LLC | Deferred gains and losses on derivatives-hedging activities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		(20)	3
Other comprehensive income before reclassifications: gains (losses)		6	(31)
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[3]	(3)	8
Other comprehensive income (loss)		3	(23)
Ending balance		(17)	(20)	3
Dominion Gas Holdings, LLC | Unrealized gains and losses on investment securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance		(66)	(61)
Other comprehensive income before reclassifications: gains (losses)		(20)	(10)
Amounts reclassified from accumulated other comprehensive income: (gains) losses	[3]	4	5
Other comprehensive income (loss)		(16)	(5)
Ending balance		$ (82)	$ (66)	$ (61)
[1]	See table below for details about these reclassifications.
[2]	See table below for details about these reclassifications.
[3]	See table below for details about these reclassifications.

Equity (Schedule of Reclassific

Equity (Schedule of Reclassifications out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions		3 Months Ended								12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operating Revenue		$ 2,556	$ 2,971	$ 2,747	$ 3,409	$ 2,943	$ 3,050	$ 2,813	$ 3,630	$ 11,683		$ 12,436		$ 13,120
Purchased gas										551		1,355		1,331
Electric fuel and other energy-related purchases										2,725		3,400		3,885
Interest and related charges										904		1,193		877
Income from continuing operations including noncontrolling interests before income taxes										2,828		1,778		2,704
Income tax expense										(905)		(452)		(892)
Income from continuing operations including noncontrolling interests										1,923		1,326		1,812
Other income										196		250		265
Impairment										31		13		8
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										(176)		152
Income tax expense										68		(59)
Income from continuing operations including noncontrolling interests										(108)		93
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										(79)		(87)
Income tax expense										29		33
Income from continuing operations including noncontrolling interests										(50)		(54)
Other income										(110)		(100)
Impairment										31		13
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										86		57
Income tax expense										(35)		(24)
Income from continuing operations including noncontrolling interests										51		33
Prior-service costs (credits)										(12)		(12)
Actuarial losses										98		69
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										(203)		130
Purchased gas										15		13
Electric fuel and other energy-related purchases										1		(7)
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										11		16
Dominion Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operating Revenue		425	365	395	531	510	391	428	569	1,716	[1]	1,898	[1]	1,937	[1]
Purchased gas	[1]									133		315		323
Interest and related charges	[1]									73		27		28
Income from continuing operations including noncontrolling interests before income taxes										740		846		762
Income tax expense										(283)		(334)		(301)
Other income										24		22		28
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										(6)		13
Income tax expense										3		(5)
Income from continuing operations including noncontrolling interests										(3)		8
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										7		8
Income tax expense										(3)		(3)
Income from continuing operations including noncontrolling interests										4		5
Prior-service costs (credits)												1
Actuarial losses										7		7
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										(6)		(2)
Purchased gas												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		$ 1,614	$ 2,058	$ 1,813	$ 2,137	$ 1,814	$ 2,053	$ 1,729	$ 1,983	7,622	[2]	7,579	[2]	7,295	[2]
Electric fuel and other energy-related purchases	[2]									2,320		2,406		2,304
Interest and related charges										443		411		369
Income from continuing operations including noncontrolling interests before income taxes										1,746		1,406		1,797
Income tax expense										(659)		(548)		(659)
Other income										68		93		86
Impairment										4		2		$ 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										1		(5)
Income tax expense										0		2
Income from continuing operations including noncontrolling interests										1		(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)		(10)
Income tax expense										4		4
Income from continuing operations including noncontrolling interests										(6)		(6)
Other income										(14)		(10)
Impairment										4
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										$ 1		$ (5)
[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) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	1,065	1,007	1,085
Granted, Shares	302	354	312
Vested, Shares	(510)	(278)	(356)
Cancelled and forfeited, Shares	(2)	(18)	(34)
Nonvested ending, Shares	855	1,065	1,007
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	$ 56.74	$ 49.35	$ 44.46
Granted, Weighted Average Grant Date Fair Value	73.26	67.98	54.70
Vested, Weighted Average Grant Date Fair Value	50.71	44.50	39
Cancelled and forfeited, Weighted Average Grant Date Fair Value	62.62	53.61	51.11
Nonvested ending, Weighted Average Grant Date Fair Value	$ 66.16	$ 56.74	$ 49.35
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	17	5	4
Granted, Shares	14	13	4
Vested, Shares	(7)	(1)	(2)
Cancelled and forfeited, Shares			(1)
Nonvested ending, Shares	24	17	5
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	$ 65.15	$ 53.85	$ 45.60
Granted, Weighted Average Grant Date Fair Value	72.72	68.83	54.17
Vested, Weighted Average Grant Date Fair Value	56.22	52.48	43.54
Cancelled and forfeited, Weighted Average Grant Date Fair Value			43.54
Nonvested ending, Weighted Average Grant Date Fair Value	$ 72.27	$ 65.15	$ 53.85

Employee Benefit Plans (Narrati

Employee Benefit Plans (Narrative) (Details) - USD ($)		3 Months Ended			12 Months Ended
		Sep. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return (loss) on plan assets					$ 72,000,000	$ 706,000,000
Expected return on pension and other postretirement plan assets					648,000,000	610,000,000
Federal subsidy received						4,000,000
Decrease in other postretirement benefit obligations due to federal subsidy					20,000,000
Net actuarial loss					25,000,000
Reduction in net periodic benefit cost for next year			$ 8,000,000	$ 36,000,000
Reduction in accumulated postretirement benefit obligation			220,000,000				$ 220,000,000
Period for reduction in net periodic benefit cost							5 years
Accumulated benefit obligation					5,800,000,000	6,000,000,000
Estimated reduction in net cumulative required contributions					$ 200,000,000
Cumulative required contribution period (years)					10 years
Expected contribution to voluntary employees beneficiary association					$ 12,000,000
Percentage coverage of US stock market					7.00%
Amounts recognized in employer matching contributions					$ 43,000,000	41,000,000	$ 40,000,000
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					35.00%
Real estate-REITs
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					16.00%
Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Expected reduction in net periodic benefit cost							40,000,000
Investment grade bonds average weighted maturity period					4 years
Minimum | External Credit Rating, Investment Grade | Fixed Income Funds
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Percentage of fund's total assets					75.00%
Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Expected reduction in net periodic benefit cost							60,000,000
Investment grade bonds average weighted maturity period					12 years
Maximum | External Credit Rating, Non Investment Grade | Fixed Income Funds
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Percentage of fund's total assets					25.00%
Virginia Electric and Power Company
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Amounts recognized in employer matching contributions					$ 18,000,000	17,000,000	16,000,000
Virginia Electric and Power Company | Other operations and maintenance expense
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Net periodic benefit cost					97,000,000	75,000,000	96,000,000
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					(16,000,000)	(18,000,000)	5,000,000
Dominion Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return (loss) on plan assets					13,000,000	157,000,000
Expected return on pension and other postretirement plan assets					150,000,000	138,000,000
Federal subsidy received						1,000,000
Net actuarial loss					3,000,000
Reduction in net periodic benefit cost for next year				2,000,000
Accumulated benefit obligation					578,000,000	604,000,000
Amounts recognized in employer matching contributions					7,000,000
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					0	1,000,000
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					(5,000,000)	(5,000,000)	1,000,000
Pension Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return (loss) on plan assets					(71,000,000)	601,000,000
Expected return on pension and other postretirement plan assets					531,000,000	$ 499,000,000	462,000,000
Actuarial (gains) losses during the year					131,000,000
Net actuarial loss					111,000,000
Medicare Part D reimbursement				$ 354,000,000
Discount rate				4.80%		4.40%
Reduction in accumulated postretirement benefit obligation	[1]		$ (22,000,000)		$ 0	$ (1,000,000)	$ (22,000,000)
Discount rate					4.40%
Expected long-term rate of return on plan assets					8.75%	8.75%	8.50%
Net periodic benefit cost					$ 44,000,000	$ 20,000,000	$ 106,000,000
Pension Benefits | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate					4.96%
Discount rate						5.20%	4.40%
Pension Benefits | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate					4.99%
Discount rate						5.30%	4.80%
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return (loss) on plan assets					$ (14,000,000)	$ 136,000,000
Expected return on pension and other postretirement plan assets					126,000,000	$ 115,000,000	$ 106,000,000
Actuarial (gains) losses during the year					10,000,000
Net actuarial loss					$ 13,000,000
Medicare Part D reimbursement				$ 28,000,000
Discount rate					4.99%	4.40%
Discount rate					4.40%	5.20%
Expected long-term rate of return on plan assets					8.75%	8.75%	8.50%
Net periodic benefit cost					$ (63,000,000)	$ (55,000,000)	$ (39,000,000)
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					(38,000,000)	(37,000,000)	$ (27,000,000)
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 (loss) on plan assets					(1,000,000)	105,000,000
Expected return on pension and other postretirement plan assets					117,000,000	$ 111,000,000	$ 92,000,000
Actuarial (gains) losses during the year					32,000,000
Net actuarial loss					5,000,000
Medicare Part D reimbursement				$ 78,000,000
Discount rate			4.80%	4.70%		4.40%	4.80%
Reduction in accumulated postretirement benefit obligation	[1]		$ (7,000,000)		$ 0	$ 0	$ (7,000,000)
Discount rate					4.40%
Expected long-term rate of return on plan assets					8.50%	8.50%	7.75%
Net periodic benefit cost					$ (31,000,000)	$ (38,000,000)	$ 2,000,000
Other Postretirement Benefits | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate					4.93%
Discount rate						4.20%	4.40%
Other Postretirement Benefits | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Discount rate					4.94%
Discount rate						5.10%	4.80%
Other Postretirement Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Actual return (loss) on plan assets					$ 1,000,000	$ 21,000,000
Expected return on pension and other postretirement plan assets					24,000,000	$ 23,000,000	$ 19,000,000
Actuarial (gains) losses during the year					7,000,000
Net actuarial loss					$ 1,000,000
Medicare Part D reimbursement				$ 9,000,000
Discount rate					4.93%	4.40%
Discount rate					4.40%
Expected long-term rate of return on plan assets					8.50%	8.50%	7.75%
Net periodic benefit cost					$ (2,000,000)	$ (5,000,000)	$ (1,000,000)
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		$ 22,000,000
Reduction in net periodic benefit credit due to amendment		$ 1,000,000
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.

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 ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jun. 30, 2013
Changes in fair value of plan assets:
Actual return (loss) on plan assets		$ 72	$ 706
Dominion Gas Holdings, LLC
Changes in fair value of plan assets:
Actual return (loss) on plan assets		13	157
Pension Benefits
Changes in benefit obligation:
Benefit obligation at beginning of year		6,667	5,625
Service cost		126	114	$ 131
Interest cost		287	290	271
Benefits paid		(246)	(236)
Actuarial (gains) losses during the year		(443)	887
Plan amendments	[1]	0	0
Settlements and curtailments	[2]	0	(13)
Medicare Part D reimbursement		0	0
Benefit obligation at end of year		6,391	6,667	5,625
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		6,480	6,113
Actual return (loss) on plan assets		(71)	601
Employer contributions		3	15
Benefits paid		(246)	(236)
Settlements	[2]	0	(13)
Fair value of plan assets at end of year		6,166	6,480	$ 6,113
Funded status at end of year		(225)	(187)
Noncurrent pension and other postretirement benefit assets		931	946
Other current liabilities		(14)	(13)
Noncurrent pension and other postretirement benefit liabilities		(1,142)	(1,120)
Net amount recognized		$ (225)	$ (187)
Discount rate			4.40%		4.80%
Weighted average rate of increase for compensation		4.22%	4.22%
Expected long-term rate of return on plan assets		8.75%	8.75%	8.50%
Pension Benefits | Minimum
Changes in fair value of plan assets:
Discount rate		4.96%
Pension Benefits | Maximum
Changes in fair value of plan assets:
Discount rate		4.99%
Pension Benefits | Dominion Gas Holdings, LLC
Changes in benefit obligation:
Benefit obligation at beginning of year		$ 638	$ 563
Service cost		15	12	$ 13
Interest cost		27	28	27
Benefits paid		(29)	(29)
Actuarial (gains) losses during the year		(43)	64
Plan amendments		0	0
Medicare Part D reimbursement		0	0
Benefit obligation at end of year		608	638	563
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		1,510	1,403
Actual return (loss) on plan assets		(14)	136
Employer contributions		0	0
Benefits paid		(29)	(29)
Fair value of plan assets at end of year		1,467	1,510	$ 1,403
Funded status at end of year		859	872
Noncurrent pension and other postretirement benefit assets		859	872
Noncurrent pension and other postretirement benefit liabilities	[3]	0	0
Net amount recognized		$ 859	$ 872
Discount rate		4.99%	4.40%
Weighted average rate of increase for compensation		3.93%	3.93%
Expected long-term rate of return on plan assets		8.75%	8.75%	8.50%
Other Postretirement Benefits
Changes in benefit obligation:
Benefit obligation at beginning of year		$ 1,571	$ 1,360
Service cost		40	32	$ 43
Interest cost		67	67	73
Benefits paid		(79)	(78)
Actuarial (gains) losses during the year		(138)	177
Plan amendments	[1]	(31)	9
Settlements and curtailments	[2]	0	0
Medicare Part D reimbursement		0	4
Benefit obligation at end of year		1,430	1,571	1,360
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		1,402	1,315
Actual return (loss) on plan assets		(1)	105
Employer contributions		12	12
Benefits paid		(31)	(30)
Settlements	[2]	0	0
Fair value of plan assets at end of year		1,382	1,402	$ 1,315
Funded status at end of year		(48)	(169)
Noncurrent pension and other postretirement benefit assets		12	10
Other current liabilities		(3)	(3)
Noncurrent pension and other postretirement benefit liabilities		(57)	(176)
Net amount recognized		$ (48)	$ (169)
Discount rate			4.40%	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%	8.50%	7.75%
Other Postretirement Benefits | Minimum
Changes in fair value of plan assets:
Discount rate		4.93%
Other Postretirement Benefits | Maximum
Changes in fair value of plan assets:
Discount rate		4.94%
Other Postretirement Benefits | Dominion Gas Holdings, LLC
Changes in benefit obligation:
Benefit obligation at beginning of year		$ 320	$ 269
Service cost		7	6	$ 7
Interest cost		14	13	12
Benefits paid		(18)	(16)
Actuarial (gains) losses during the year		(31)	38
Plan amendments		0	9
Medicare Part D reimbursement		0	1
Benefit obligation at end of year		292	320	269
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		288	273
Actual return (loss) on plan assets		1	21
Employer contributions		12	10
Benefits paid		(18)	(16)
Fair value of plan assets at end of year		283	288	$ 273
Funded status at end of year		(9)	(32)
Noncurrent pension and other postretirement benefit assets		0	0
Noncurrent pension and other postretirement benefit liabilities	[3]	(9)	(32)
Net amount recognized		$ (9)	$ (32)
Discount rate		4.93%	4.40%
Weighted average rate of increase for compensation		3.93%	3.93%
Expected long-term rate of return on plan assets		8.50%	8.50%	7.75%
[1]	2015 amount relates primarily to a plan amendment that changed retiree medical benefits for certain nonunion employees after Medicare eligibility.
[2]	Relates primarily to a settlement charge for certain executives.
[3]	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 ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	$ 5,728	$ 5,970
Fair value of plan assets	4,571	4,838
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	359	1,564
Fair value of plan assets	299	1,385
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	292	320
Fair value of plan assets	$ 283	$ 288

Employee Benefit Plans (Accumul

Employee Benefit Plans (Accumulated Benefit Obligation in Excess of Plan Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Accumulated benefit obligation	$ 5,198	$ 5,370
Fair value of plan assets	$ 4,571	$ 4,838

Employee Benefit Plans (Bene120

Employee Benefit Plans (Benefit Payments Expected Future Service) (Details) $ in Millions	Dec. 31, 2015USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
2,016	$ 288
2,017	303
2,018	324
2,019	337
2,020	359
2021-2025	2,023
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
2,016	35
2,017	37
2,018	39
2,019	40
2,020	41
2021-2025	208
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
2,016	92
2,017	96
2,018	99
2,019	100
2,020	102
2021-2025	512
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
2,016	18
2,017	19
2,018	21
2,019	21
2,020	21
2021-2025	$ 107

Employee Benefit Plans (Fair va

Employee Benefit Plans (Fair values of pension and post retirement plan assets by asset category) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		$ 6,166	$ 6,480	$ 6,113
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,467	1,510	1,403
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,382	1,402	1,315
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		283	288	$ 273
Collective Bargaining Agreement | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4,082	4,201
Total recorded at NAV	[1]	2,074	2,268
Pension plan assets by asset category	[2]	6,156	6,469
Pending sales of securities		112	31
Net accrued income		16	18
Pending purchases of securities		118	38
Collective Bargaining Agreement | Pension Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		16	38
Collective Bargaining Agreement | Pension Benefits | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,178	1,313
Collective Bargaining Agreement | Pension Benefits | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		475	530
Collective Bargaining Agreement | Pension Benefits | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		286	234
Collective Bargaining Agreement | Pension Benefits | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		493	403
Collective Bargaining Agreement | Pension Benefits | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[1]	330	360
Total recorded at NAV	[1],[3]	1,200	1,235
John Hancock insurance contracts held		330	360
Collective Bargaining Agreement | Pension Benefits | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		712	711
Collective Bargaining Agreement | Pension Benefits | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		358	416
Collective Bargaining Agreement | Pension Benefits | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		74	70
Collective Bargaining Agreement | Pension Benefits | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		70	86
Collective Bargaining Agreement | Pension Benefits | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		90	40
Collective Bargaining Agreement | Pension Benefits | Real estate-REITs | Real estate-Partnerships
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[1]	153	209
Collective Bargaining Agreement | Pension Benefits | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[3]	465	518
Collective Bargaining Agreement | Pension Benefits | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[3]	170	144
Collective Bargaining Agreement | Pension Benefits | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[1]	86	162
Collective Bargaining Agreement | Pension Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2,667	2,668
Collective Bargaining Agreement | Pension Benefits | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		16	13
Collective Bargaining Agreement | Pension Benefits | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,178	1,313
Collective Bargaining Agreement | Pension Benefits | Level 1 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		475	530
Collective Bargaining Agreement | Pension Benefits | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		286	234
Collective Bargaining Agreement | Pension Benefits | Level 1 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		493	403
Collective Bargaining Agreement | Pension Benefits | Level 1 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[1]	0	0
Collective Bargaining Agreement | Pension Benefits | Level 1 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		40	45
Collective Bargaining Agreement | Pension Benefits | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		60	74
Collective Bargaining Agreement | Pension Benefits | Level 1 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		20	10
Collective Bargaining Agreement | Pension Benefits | Level 1 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		9	6
Collective Bargaining Agreement | Pension Benefits | Level 1 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		90	40
Collective Bargaining Agreement | Pension Benefits | Level 2
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,415	1,533
Collective Bargaining Agreement | Pension Benefits | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	25
Collective Bargaining Agreement | Pension Benefits | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 2 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 2 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 2 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[1]	330	360
Collective Bargaining Agreement | Pension Benefits | Level 2 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		672	666
Collective Bargaining Agreement | Pension Benefits | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		298	342
Collective Bargaining Agreement | Pension Benefits | Level 2 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		54	60
Collective Bargaining Agreement | Pension Benefits | Level 2 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		61	80
Collective Bargaining Agreement | Pension Benefits | Level 2 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[1]	0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Level 3 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		970	979
Total recorded at NAV	[3]	494	529
Pension plan assets by asset category	[4]	1,464	1,508
Pending sales of securities		27	7
Net accrued income		4
Pending purchases of securities		28	9
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4	9
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		280	306
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		113	124
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		68	54
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		117	94
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[5]	78	84
Total recorded at NAV	[3],[5]	286	288
John Hancock insurance contracts held		78	84
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		169	166
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		85	97
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		18	16
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		16	20
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		22	9
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Real estate-REITs | Real estate-Partnerships
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[3]	36	48
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[3]	111	121
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[3]	40	34
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[3]	21	38
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		634	621
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4	3
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		280	306
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		113	124
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		68	54
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		117	94
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[5]	0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		9	11
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		14	17
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		5	2
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2	1
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 1 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		22	9
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		336	358
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	6
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[5]	78	84
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		160	155
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		71	80
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		13	14
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		14	19
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 2 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[5]	0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Pension Benefits | Dominion Gas Holdings, LLC | Level 3 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		752	762
Total recorded at NAV	[6]	630	640
Pension plan assets by asset category	[6]	1,382	1,402
Collective Bargaining Agreement | Other Postretirement Plans | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2	8
Collective Bargaining Agreement | Other Postretirement Plans | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		468	514
Collective Bargaining Agreement | Other Postretirement Plans | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		26	28
Collective Bargaining Agreement | Other Postretirement Plans | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		107	102
Collective Bargaining Agreement | Other Postretirement Plans | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		27	21
Collective Bargaining Agreement | Other Postretirement Plans | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[7]	18	19
Total recorded at NAV	[6],[7]	543	536
John Hancock insurance contracts held		18	19
Collective Bargaining Agreement | Other Postretirement Plans | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		39	38
Collective Bargaining Agreement | Other Postretirement Plans | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		20	22
Collective Bargaining Agreement | Other Postretirement Plans | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4	4
Collective Bargaining Agreement | Other Postretirement Plans | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4	4
Collective Bargaining Agreement | Other Postretirement Plans | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		37	2
Collective Bargaining Agreement | Other Postretirement Plans | Real estate-REITs | Real estate-Partnerships
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	14	19
Collective Bargaining Agreement | Other Postretirement Plans | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	54	58
Collective Bargaining Agreement | Other Postretirement Plans | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	14	18
Collective Bargaining Agreement | Other Postretirement Plans | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	5	9
Collective Bargaining Agreement | Other Postretirement Plans | Level 1
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		673	676
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	1
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		468	514
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		26	28
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		107	102
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		27	21
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[7]	0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2	3
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		3	4
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	1
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 1 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		37	2
Collective Bargaining Agreement | Other Postretirement Plans | Level 2
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		79	86
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	7
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[7]	18	19
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		37	35
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		17	18
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		3	3
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		3	4
Collective Bargaining Agreement | Other Postretirement Plans | Level 2 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Non-U.S. equity: | Other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[7]	0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Fixed Income: | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Fixed Income: | State and municipal
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Fixed Income: | Other securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Level 3 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		137	141
Pension plan assets by asset category	[6]	283	288
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	2
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		102	113
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		24	26
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6],[8]	132	129
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		11	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Real estate-REITs | Real estate-Partnerships
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	2	2
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Other alternative investments: | Private equity
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	11	12
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Other alternative investments: | Debt
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	1	4
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Other alternative investments: | Hedge funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[6]	146	147
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		137	139
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		102	113
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		24	26
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 1 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		11	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	2
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	2
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 2 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Non-U.S. equity: | Large Cap
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		0	0
Collective Bargaining Agreement | Other Postretirement Plans | Dominion Gas Holdings, LLC | Level 3 | Real estate-REITs | Real estate-REITs
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		$ 0	$ 0
[1]	Common/collective trust funds include $330 million and $360 million of John Hancock insurance contracts held at December 31, 2015 and 2014, 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 $112 million, net accrued income of $16 million, and excludes net assets related to pending purchases of securities of $118 million at December 31, 2015. 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]	These investments that are measured at fair value using the NAV per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Consolidated Balance Sheets.
[4]	Includes net assets related to pending sales of securities of $27 million, net accrued income of $4 million, and excludes net assets related to pending purchases of securities of $28 million at December 31, 2015. 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.
[5]	Common/collective trust funds include $78 million and $84 million of John Hancock insurance contracts held at December 31, 2015 and 2014, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
[6]	These investments that are measured at fair value using the NAV per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Consolidated Balance Sheets.
[7]	Common/collective trust funds include $18 million and $19 million of John Hancock insurance contracts held at December 31, 2015 and 2014, respectively. See below for a description of the individual investments included within this line item, and the nature and risk of each respective fund.
[8]	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 (Net Per

Employee Benefit Plans (Net Periodic Benefit (Credit) Cost and Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets		$ (648)	$ (610)
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		(150)	(138)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost		126	114	131
Interest cost		287	290	271
Expected return on plan assets		(531)	(499)	(462)
Amortization of prior service (credit) cost		(2)	(3)	(3)
Amortization of net actuarial loss		160	111	165
Settlements and curtailments	[1]	0	1	(2)
Special termination benefits		0	0	0
Net periodic benefit (credit) cost		44	20	106
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss		159	784	(968)
Prior service (credit) cost		0	0	1
Settlements and curtailments	[1]	0	(1)	(22)
Total recognized in other comprehensive income and regulatory assets and liabilities		$ (3)	$ 669	$ (1,157)
Significant assumptions used to determine periodic cost:
Discount rate		4.40%
Expected long-term rate of return on plan assets		8.75%	8.75%	8.50%
Weighted average rate of increase for compensation		4.22%	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		$ 15	$ 12	$ 13
Interest cost		27	28	27
Expected return on plan assets		(126)	(115)	(106)
Amortization of prior service (credit) cost		(1)	(1)	(1)
Amortization of net actuarial loss		20	19	26
Net periodic benefit (credit) cost		(63)	(55)	(39)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss		97	43	(127)
Prior service (credit) cost		0	0	0
Total recognized in other comprehensive income and regulatory assets and liabilities		$ 76	$ 23	$ (154)
Significant assumptions used to determine periodic cost:
Discount rate		4.40%	5.20%
Expected long-term rate of return on plan assets		8.75%	8.75%	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		$ 40	$ 32	$ 43
Interest cost		67	67	73
Expected return on plan assets		(117)	(111)	(92)
Amortization of prior service (credit) cost		27	28	15
Amortization of net actuarial loss		6	2	7
Settlements and curtailments	[1]	0	0	(15)
Special termination benefits		0	0	1
Net periodic benefit (credit) cost		(31)	(38)	2
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss		(18)	183	(255)
Prior service (credit) cost		(31)	9	(215)
Settlements and curtailments	[1]	0	0	(7)
Total recognized in other comprehensive income and regulatory assets and liabilities		$ (28)	$ 218	$ (469)
Significant assumptions used to determine periodic cost:
Discount rate		4.40%
Expected long-term rate of return on plan assets		8.50%	8.50%	7.75%
Weighted average rate of increase for compensation		4.22%	4.22%	4.22%
Healthcare cost trend rate	[2]	7.00%	7.00%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	[2]	5.00%	5.00%	4.60%
Year that the rate reaches the ultimate trend rate	[2],[3]	2,019	2,018	2,062
Other Postretirement Plans | Minimum
Significant assumptions used to determine periodic cost:
Discount rate			4.20%	4.40%
Other Postretirement Plans | Maximum
Significant assumptions used to determine periodic cost:
Discount rate			5.10%	4.80%
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Service cost		$ 7	$ 6	$ 7
Interest cost		14	13	12
Expected return on plan assets		(24)	(23)	(19)
Amortization of prior service (credit) cost		1	1	3
Amortization of net actuarial loss		2	0	2
Net periodic benefit (credit) cost		(2)	(5)	(1)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss		(9)	40	(40)
Prior service (credit) cost		0	10	0
Total recognized in other comprehensive income and regulatory assets and liabilities		$ (10)	$ 51	$ (39)
Significant assumptions used to determine periodic cost:
Discount rate		4.40%
Expected long-term rate of return on plan assets		8.50%	8.50%	7.75%
Weighted average rate of increase for compensation		3.93%	3.93%	3.93%
Healthcare cost trend rate	[2]	7.00%	7.00%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	[2]	5.00%	5.00%	4.60%
Year that the rate reaches the ultimate trend rate	[2],[3]	2,019	2,018	2,062
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 ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		$ (474)	$ (416)	$ (324)
Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		(99)	(86)	$ (58)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		2,381	2,382
Prior service (credit) cost		5	7
Total	[1]	2,386	2,389
Amount included in AOCI		1,400	1,400
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		380	303
Prior service (credit) cost		1	1
Total	[1]	381	304
Amount included in AOCI		138	112
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		114	139
Prior service (credit) cost		(237)	(233)
Total	[1]	(123)	(94)
Amount included in AOCI		(90)	(81)
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		33	43
Prior service (credit) cost		7	7
Total	[1]	$ 40	$ 50
[1]	As of December 31, 2015, of the $2.4 billion and $(123) million related to pension benefits and other postretirement benefits, $1.4 billion and $(90) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. 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.

Employee Benefit Plans (Compone

Employee Benefit Plans (Components of AOCI and Regulatory Assets and Liabilities) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
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	111
Prior service (credit) cost	1
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	13
Prior service (credit) cost	0
Other Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	5
Prior service (credit) cost	(28)
Other Postretirement Plans | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	1
Prior service (credit) cost	$ 1

Employee Benefit Plans (Effect

Employee Benefit Plans (Effect of One Percentage Point Change on Benefit Plans) (Details) - Other Postretirement Plans $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Defined Benefit Plan Disclosure [Line Items]
Effect of one percentage point increase on total of service and interest cost components	$ 21
Effect of one percentage point increase on other postretirement benefit obligation	157
Effect of one percentage point decrease on total of service and interest cost components	(13)
Effect of one percentage point decrease on other postretirement benefit obligation	(129)
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	34
Effect of one percentage point decrease on total of service and interest cost components	(3)
Effect of one percentage point decrease on other postretirement benefit obligation	$ (26)

Commitments and Contingencie126

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

1 Months Ended

12 Months Ended

65 Months Ended

Jun. 30, 2015Party

Apr. 30, 2015Facility

Oct. 31, 2014Facility

Jun. 30, 2014Unit

May. 31, 2014USD ($)

Jul. 31, 2013Unit

Sep. 30, 2011Party

Jul. 31, 2011StateGroupMW

Dec. 31, 2015USD ($)SiteParty

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)

Dec. 31, 2015USD ($)Site

Sep. 30, 2015Facility

Loss Contingencies [Line Items]

Compliance extension period

1 year

Number of coal fired generating units | Unit

2

3

Capital expenditures

$ 5,575,000,000

$ 5,345,000,000

$ 4,065,000,000

Period for consideration of CO2 emissions for biomass projects

3 years

Number of parties ordered specific remedial action | Party

22

Maximum civil penalties per day

$ 37,500

Number of former manufactured gas plant sites | Site

17

17

Charges associated with future ash pond and landfill closure costs

$ 99,000,000

121,000,000

0

ARO recorded related to future ash pond and landfill closure costs

315,000,000

[1]

40,000,000

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

CSAPR

Loss Contingencies [Line Items]

Number of states under EPA Replacement Rule | State

28

Emissions of fossil fuel fired electric generating units | MW

25

Number of groups of affected states | Group

2

National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines

Loss Contingencies [Line Items]

Capital expenditures

2,000,000

Clean Water Act

Loss Contingencies [Line Items]

Number of facilities | Facility

14

Clean Water Act | Final Rule to Revise Effluent Limitations Guidelines for Steam Electric Power Generating Category | EPA

Loss Contingencies [Line Items]

Number of facilities subject to ruling | Facility

8

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

$ 6,000,000

Virginia Electric and Power Company

Loss Contingencies [Line Items]

Capital expenditures

$ 2,474,000,000

2,911,000,000

2,394,000,000

Number of former manufactured gas plant sites | Site

3

3

Charges associated with future ash pond and landfill closure costs

$ 99,000,000

121,000,000

0

ARO recorded related to future ash pond and landfill closure costs

289,000,000

[1]

28,000,000

Virginia Electric and Power Company | Notice from Southern Environmental Law Center Alleging Clean Water Act Violations at Possum Point | EPA | Possum Point Power Station | Other operations and maintenance expense

Loss Contingencies [Line Items]

Charges associated with future ash pond and landfill closure costs

121,000,000

Virginia Electric and Power Company | Environmental Protection Agency Final Rule Regulating Management of Coal Combustion Residual | EPA | Facilities Subject to Coal Combustion Residual Final Rule

Loss Contingencies [Line Items]

Number of facilities with CCR | Facility

8

ARO recorded related to future ash pond and landfill closure costs

386,000,000

Virginia Electric and Power Company | Environmental Protection Agency Final Rule Regulating Management of Coal Combustion Residual | EPA | Facilities Subject to Coal Combustion Residual Final Rule | Other operations and maintenance expense

Loss Contingencies [Line Items]

Charges associated with future ash pond and landfill closure costs

99,000,000

Virginia Electric and Power Company | Environmental Protection Agency Final Rule Regulating Management of Coal Combustion Residual | EPA | Facilities Subject to Coal Combustion Residual Final Rule | Other Noncurrent Liabilities

Loss Contingencies [Line Items]

Reversal of contingent liability

121,000,000

Virginia Electric and Power Company | Environmental Protection Agency Final Rule Regulating Management of Coal Combustion Residual | EPA | Facilities Subject to Coal Combustion Residual Final Rule | Remediation Property for Sale, Abandonment or Disposal

Loss Contingencies [Line Items]

Increase in property plant and equipment associated with asset retirement costs

166,000,000

Virginia Electric and Power Company | Clean Water Act

Loss Contingencies [Line Items]

Number of facilities | Facility

11

Dominion Gas Holdings, LLC

Loss Contingencies [Line Items]

Capital expenditures

$ 795,000,000

719,000,000

$ 650,000,000

Number of former manufactured gas plant sites | Site

12

12

ARO recorded related to future ash pond and landfill closure costs

$ 5,000,000

$ 2,000,000

Cove Point | Liquefaction Project | Pending Litigation

Loss Contingencies [Line Items]

Number of parties | Party

2

Cove Point | Liquefaction Project | Judicial Ruling

Loss Contingencies [Line Items]

Number of parties | Party

1

[1]

Primarily reflects future ash pond and landfill closure costs at certain utility generation facilities. See Note 22 for further information.

Commitments and Contingencie127

Commitments and Contingencies (Nuclear Operations) (Narrative) (Details) $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2013$ / kWh	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Loss Contingencies [Line Items]
Amount of coverage purchased from commercial insurance pools		$ 375
Amount that could be assessed for each licensed reactor		127
Amount that could be assessed for each licensed reactor per reactor		19
Maximum assessment for premiums on insurance policy		84
Maximum assessment for insurance policy		23
Current fee per kWh for electricity paid by civilian nuclear power generators | $ / kWh	1
Waste fee recognized		16
Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables		87	$ 69
Millstone Unit 1
Loss Contingencies [Line Items]
Minimum financial assurance			2,900
Surry and North Anna
Loss Contingencies [Line Items]
Settlement amount		8	27
Millstone
Loss Contingencies [Line Items]
Settlement amount		17	17
Kewaunee
Loss Contingencies [Line Items]
Settlement amount		7
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Maximum assessment for premiums on insurance policy		48
Maximum assessment for insurance policy		10
Waste fee recognized		10
Virginia Electric and Power Company | Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables		$ 54	41
Virginia Electric and Power Company | Kewaunee
Loss Contingencies [Line Items]
Minimum financial assurance			$ 1,800

Commitments and Contingencie128

Commitments and Contingencies (Nuclear Insurance) (Details)	Dec. 31, 2015USD ($)
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 ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Long-term Purchase Commitment [Line Items]
Present value of total commitment for capacity payments		$ 577
Purchased electric capacity
Long-term Purchase Commitment [Line Items]
2,016	[1]	249
2,017	[1]	157
2,018	[1]	104
2,019	[1]	65
2,020	[1]	52
Thereafter	[1]	46
Total	[1]	673
Payments		305	$ 330	$ 345
Energy payments
Long-term Purchase Commitment [Line Items]
Payments		$ 198	$ 304	$ 236
[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, 2015, the present value of Virginia Power's total commitment for capacity payments is $577 million. Capacity payments totaled $305 million, $330 million, and $345 million, and energy payments totaled $198 million, $304 million, and $236 million for the years ended 2015, 2014 and 2013, respectively.

Commitments and Contingencie130

Commitments and Contingencies (Lease Commitments) (Details) $ in Millions	Dec. 31, 2015USD ($)
Loss Contingencies [Line Items]
2,016	$ 67
2,017	62
2,018	54
2,019	43
2,020	25
Thereafter	153
Total	404
Virginia Electric and Power Company
Loss Contingencies [Line Items]
2,016	30
2,017	27
2,018	23
2,019	17
2,020	14
Thereafter	27
Total	138
Dominion Gas Holdings, LLC
Loss Contingencies [Line Items]
2,016	26
2,017	25
2,018	23
2,019	18
2,020	6
Thereafter	19
Total	$ 117

Commitments and Contingencie131

Commitments and Contingencies (Lease Commitments) (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Loss Contingencies [Line Items]
Rental expense	$ 99	$ 92	$ 101
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Rental expense	51	43	42
Dominion Gas Holdings, LLC
Loss Contingencies [Line Items]
Rental expense	$ 37	$ 35	$ 15

Commitments and Contingencie132

Commitments and Contingencies (Guarantees, Surety Bonds and Letters of Credit) (Narrative) (Details) $ in Millions	Dec. 31, 2015USD ($)
Guarantor Obligations [Line Items]
Exposure under guarantees	$ 6,562
Purchased surety bonds	92
Authorized issuance of standby letters of credit	59
Debt
Guarantor Obligations [Line Items]
Exposure under guarantees	27	[1]
Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Purchased surety bonds	34
Virginia Electric and Power Company | Debt
Guarantor Obligations [Line Items]
Exposure under guarantees	14
Dominion Gas Holdings, LLC
Guarantor Obligations [Line Items]
Purchased surety bonds	23
Third Party and Equity Method Investee
Guarantor Obligations [Line Items]
Estimate of possible loss	74
Exposure under guarantees	$ 39
[1]	Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, Dominion would be obligated to repay such amounts.

Commitments and Contingencie133

Commitments and Contingencies (Subsidiary Guarantees) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)guaranteeSubsidiary
Guarantor Obligations [Line Items]
Stated Limit	$ 6,562
Value	$ 1,712	[1]
Number of DEI subsidiaries | Subsidiary	2
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]
Stated Limit	39
Debt
Guarantor Obligations [Line Items]
Stated Limit	27	[2]
Value	27	[1],[2]
Commodity transactions
Guarantor Obligations [Line Items]
Stated Limit	2,371	[3]
Value	932	[1],[3]
Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	184	[4]
Value	75	[1],[4]
Solar
Guarantor Obligations [Line Items]
Stated Limit	1,555	[5]
Value	647	[1],[5]
Other
Guarantor Obligations [Line Items]
Stated Limit	515	[6]
Value	31	[1],[6]
Through 2019 | Third Party and Equity Method Investee
Guarantor Obligations [Line Items]
Stated Limit	55
Virginia Electric and Power Company | Debt
Guarantor Obligations [Line Items]
Stated Limit	14
Millstone | Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	150
Kewaunee | Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	60
Cove Point
Guarantor Obligations [Line Items]
Stated Limit	$ 150
Number of guarantees with no stated limit | guarantee	2
Number of guarantees | guarantee	1
Aggregate limit for guarantees	$ 1,750
Annual draw limit	175
Cove Point | Nuclear obligations
Guarantor Obligations [Line Items]
Stated Limit	1,910	[7]
Value	$ 0	[1],[7]
[1]	Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2015 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 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, 2015, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $55 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) (Detail

Credit Risk (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)customer	Dec. 31, 2014USD ($)
Concentration Risk [Line Items]
Gross credit exposure	$ 149
Additional collateral to be posted if the credit-related contingent features were triggered	12	$ 20
Collateral already posted	0	1
Aggregate fair value of derivative instruments in a liability position and not fully collateralized with cash	$ 49	$ 49
Investment Grade Counterparties | Investment Grade
Concentration Risk [Line Items]
Concentration of credit risk	79.00%
CounterpartyA
Concentration Risk [Line Items]
Amount of exposure	$ 31
Customer Concentration Risk | Sales Revenue, Net | DTI
Concentration Risk [Line Items]
Concentration of credit risk	94.00%
Number of customers | customer	266
Customer Concentration Risk | Sales Revenue, Net | DTI | Ten Largest Customers
Concentration Risk [Line Items]
Concentration of credit risk	42.00%
Number of customers | customer	10
Customer Concentration Risk | Sales Revenue, Net | DTI | Thirty Largest Customers
Concentration Risk [Line Items]
Concentration of credit risk	72.00%
Number of customers | customer	30
Customer Concentration Risk | Sales Revenue, Net | East Ohio
Concentration Risk [Line Items]
Concentration of credit risk	98.00%

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Derivative assets		$ 388	$ 719
Derivative liabilities		343	794
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Derivative assets		127	113
Derivative liabilities		86	87
Commodity purchases from affiliates		555	543	$ 417
Services provided by affiliates	[1]	422	432	415
Services provided to affiliates		22	22	21
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		316	219
Virginia Electric and Power Company | Other Deferred Charges and Other Assets
Related Party Transaction [Line Items]
Amounts due from affiliate associated with benefit plan		77	37
Virginia Electric and Power Company | Affiliated Entity
Related Party Transaction [Line Items]
Derivative assets		13
Derivative liabilities		22
Virginia Electric and Power Company | Dominion
Related Party Transaction [Line Items]
Short term demand note borrowings		376	427
Dominion Gas Holdings, LLC
Related Party Transaction [Line Items]
Derivative assets		11	2
Derivative liabilities		14	9
Amounts due to affiliate associated with benefit plan	[2]	1	3
Amounts due from affiliate associated with benefit plan		4	5
Services provided by affiliates	[3]	101	17	4
Services provided to affiliates		69	84	109
Purchases of natural gas and transportation and storage services from affiliates		10	34	31
Customer receivables from related parties	[4]	7	17
Affiliated notes receivable	[5]	14	9
Dominion Gas Holdings, LLC | Revolving Credit Facility | IRCA
Related Party Transaction [Line Items]
Borrowings under IRCA		95	384
Interest charges			4	35
Dominion Gas Holdings, LLC | Services provided by affiliates
Related Party Transaction [Line Items]
Purchases of natural gas and transportation and storage services from affiliates	[6]	133	106	$ 116
Dominion Gas Holdings, LLC | Noncurrent Pension and Other Postretirement Benefit Assets
Related Party Transaction [Line Items]
Amounts due from Dominion		652	614
Dominion Gas Holdings, LLC | Other Deferred Credits and Other Liabilities
Related Party Transaction [Line Items]
Amounts due to affiliate associated with benefit plan		$ 2	$ 7
[1]	Includes capitalized expenditures.
[2]	Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.
[3]	Amounts primarily attributable to Atlantic Coast Pipeline.
[4]	Represents amounts due from Atlantic Coast Pipeline, a related party VIE.
[5]	Amounts are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.
[6]	Includes capitalized expenditures.

Operating Segments (Narrative)

Operating Segments (Narrative) (Details) - USD ($) $ in Millions		3 Months Ended					12 Months Ended
		Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Total operating expenses							$ 8,147	$ 9,715	$ 9,804
Charges associated with future ash pond and landfill closure costs							99	121	0
Charge recognized							0	374	0
Charge recognized, net of tax					$ 191	$ 193
Income (loss) from discontinued operations	[1]						0	0	92
Asset disposition adjustment								42
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Total operating expenses							5,501	5,855	5,215
Charges associated with future ash pond and landfill closure costs							99	121	0
Charge related to settlement offer, net of tax				$ 74
Charge recognized							0	374	0
Charge recognized, net of tax					$ 191
Virginia Electric and Power Company | Virginia Regulation | Deferred Fuel Costs
Segment Reporting Information [Line Items]
Write off of deferred fuel cost, net of tax		$ 52
Virginia Electric and Power Company | Facilities Subject to Coal Combustion Residual Final Rule
Segment Reporting Information [Line Items]
Charge related to settlement offer, net of tax		$ 32	$ 28
Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
Total operating expenses							927	1,047	1,175
Asset disposition adjustment								3
Operating Segments
Segment Reporting Information [Line Items]
Income (loss) from discontinued operations									92
Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Total operating expenses							391	970	452
Net expenses attributable to other operating segments							136	544	184
Income (loss) from discontinued operations									92
Asset disposition adjustment	[2]							0
Operating Segments | Dominion Generation
Segment Reporting Information [Line Items]
Charges associated with future ash pond and landfill closure costs								121
Charge related to settlement offer, net of tax								74
Income (loss) from discontinued operations	[3]								0
Asset disposition adjustment	[4]							32
Net gain on investments									81
Net gain on investments after tax									49
Operating Segments | Dominion Generation | Legislation enacted
Segment Reporting Information [Line Items]
Charge recognized								374
Charge recognized, net of tax								248
Operating Segments | Dominion Generation | Virginia Regulation | Deferred Fuel Costs
Segment Reporting Information [Line Items]
Write offs of deferred fuel costs							85
Write off of deferred fuel cost, net of tax							52
Operating Segments | Dominion Generation | Facilities Subject to Coal Combustion Residual Final Rule
Segment Reporting Information [Line Items]
Charges associated with future ash pond and landfill closure costs							99
Charge related to settlement offer, net of tax							60
Operating Segments | Dominion Energy
Segment Reporting Information [Line Items]
Income (loss) from discontinued operations	[3]								0
Asset disposition adjustment	[5]							10
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
Operating Segments | Dominion Energy | Legislation enacted
Segment Reporting Information [Line Items]
Charge recognized								319
Charge recognized, net of tax								193
Operating Segments | 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
Operating Segments | Virginia Electric and Power Company | Corporate and Other
Segment Reporting Information [Line Items]
Total operating expenses							153	342	47
Operating Segments | Virginia Electric and Power Company | Dominion Generation
Segment Reporting Information [Line Items]
Charges associated with future ash pond and landfill 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
Operating Segments | Virginia Electric and Power Company | Dominion Generation | Legislation enacted
Segment Reporting Information [Line Items]
Charge recognized								374
Charge recognized, net of tax								248
Operating Segments | Virginia Electric and Power Company | Dominion Generation | Virginia Regulation | Deferred Fuel Costs
Segment Reporting Information [Line Items]
Write offs of deferred fuel costs							85
Write off of deferred fuel cost, net of tax							52
Operating Segments | Virginia Electric and Power Company | Dominion Generation | Facilities Subject to Coal Combustion Residual Final Rule
Segment Reporting Information [Line Items]
Charges associated with future ash pond and landfill closure costs							99
Charge related to settlement offer, net of tax							60
Operating Segments | Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
Net expenses attributable to other operating segments							13		41
Impairment charge									55
Impairment charge after tax									33
Ceiling test impairment charge							16
Ceiling test impairment charge, net of tax							10
Severance costs									14
Severance costs net of tax									8
Operating Segments | Dominion Gas Holdings, LLC | Corporate and Other
Segment Reporting Information [Line Items]
Net expenses attributable to other operating segments							$ 21	9	$ 49
Asset disposition adjustment	[2]							0
Operating Segments | Dominion Gas Holdings, LLC | Dominion Generation
Segment Reporting Information [Line Items]
Asset disposition adjustment								0
Operating Segments | Dominion Gas Holdings, LLC | Dominion Energy
Segment Reporting Information [Line Items]
Asset disposition adjustment	[5]							$ 3
[1]	Includes income tax benefit of $43 million in 2013.
[2]	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.
[3]	Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.
[4]	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
[5]	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 ($) $ in Millions		3 Months Ended								12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Segment Reporting Information [Line Items]
Operating Revenue		$ 2,556	$ 2,971	$ 2,747	$ 3,409	$ 2,943	$ 3,050	$ 2,813	$ 3,630	$ 11,683		$ 12,436		$ 13,120
Equity in earnings of equity method investees										56		46		14
Income tax expense										905		452		892
Loss from discontinued operations, net of tax	[1]									0		0		(92)
Net income (loss) attributable to Dominion		357	593	413	536	243	529	159	379	1,899		1,310		1,697
Capital expenditures										5,575		5,345		4,065
Investment in equity method affiliates		1,320				1,081				1,320		1,081
Total assets		58,797				54,327				58,797		54,327
Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										11,683		12,436		13,120
Depreciation, depletion and amortization										1,395		1,292		1,208
Equity in earnings of equity method investees										56		46		14
Interest income										58		68		54
Interest and related charges										904		1,193		877
Income tax expense										905		452		892
Loss from discontinued operations, net of tax														(92)
Net income (loss) attributable to Dominion										1,899		1,310		1,697
Capital expenditures										5,993		5,551		4,104
Investment in equity method affiliates		1,320				1,081				1,320		1,081
Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue	[2]									(1,284)		(1,504)		(1,640)
Adjustments & Eliminations
Segment Reporting Information [Line Items]
Operating Revenue	[2]									741		949		1,062
Depreciation, depletion and amortization	[2]									0		0		0
Equity in earnings of equity method investees	[2]									0		0		0
Interest income	[2]									(44)		(33)		(66)
Interest and related charges	[2]									(44)		(33)		(66)
Income tax expense	[2]									0		0		0
Loss from discontinued operations, net of tax	[2]													0
Net income (loss) attributable to Dominion	[2]									0		0		0
Capital expenditures	[2]									0		0		0
Investment in equity method affiliates	[2]	0				0				0		0
Total assets	[2]	(5,800)				(4,300)				(5,800)		(4,300)
Segment Reconciling Items and Intersegment Eliminations
Segment Reporting Information [Line Items]
Operating Revenue	[2]									(543)		(555)		(578)
DVP
Segment Reporting Information [Line Items]
Operating Revenue										2,111		1,936		1,834
DVP | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										2,091		1,918		1,825
Depreciation, depletion and amortization										498		462		427
Equity in earnings of equity method investees										0		0		0
Interest income										0		0		0
Interest and related charges										230		205		175
Income tax expense										307		317		287
Loss from discontinued operations, net of tax														0
Net income (loss) attributable to Dominion										490		502		475
Capital expenditures										1,607		1,652		1,361
Investment in equity method affiliates		0				0				0		0
Total assets		14,700				13,000				14,700		13,000
DVP | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue										20		18		9
Dominion Generation
Segment Reporting Information [Line Items]
Operating Revenue	[2]									7,016		7,169		6,947
Dominion Generation | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue	[2]									7,001		7,135		6,664
Depreciation, depletion and amortization	[2]									591		514		511
Equity in earnings of equity method investees	[2]									(15)		(18)		(14)
Interest income	[2]									64		58		59
Interest and related charges	[2]									262		240		220
Income tax expense	[2]									465		365		436
Loss from discontinued operations, net of tax	[2]													0
Net income (loss) attributable to Dominion	[2]									1,120		1,061		963
Capital expenditures	[2]									2,190		2,466		1,605
Investment in equity method affiliates	[2]	245				262				245		262
Total assets	[2]	25,600				23,900				25,600		23,900
Dominion Generation | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue	[2]									15		34		283
Dominion Energy
Segment Reporting Information [Line Items]
Operating Revenue	[2]									2,572		3,326		4,305
Dominion Energy | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue	[2]									1,877		2,446		3,566
Depreciation, depletion and amortization	[2]									262		243		235
Equity in earnings of equity method investees	[2]									60		54		21
Interest income	[2]									25		23		19
Interest and related charges	[2]									27		11		26
Income tax expense	[2]									423		463		456
Loss from discontinued operations, net of tax	[2]													0
Net income (loss) attributable to Dominion	[2]									680		717		711
Capital expenditures	[2]									2,153		1,329		1,043
Investment in equity method affiliates	[2]	1,042				796				1,042		796
Total assets	[2]	15,300				13,000				15,300		13,000
Dominion Energy | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue	[2]									695		880		739
Corporate and Other
Segment Reporting Information [Line Items]
Operating Revenue										527		560		612
Corporate and Other | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										(27)		(12)		3
Depreciation, depletion and amortization										44		73		35
Equity in earnings of equity method investees										11		10		7
Interest income										13		20		42
Interest and related charges										429		770		522
Income tax expense										(290)		(693)		(287)
Loss from discontinued operations, net of tax														(92)
Net income (loss) attributable to Dominion										(391)		(970)		(452)
Capital expenditures										43		104		95
Investment in equity method affiliates		33				23				33		23
Total assets		9,000				8,700				9,000		8,700
Corporate and Other | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue										554		572		609
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating Revenue		1,614	2,058	1,813	2,137	1,814	2,053	1,729	1,983	7,622	[3]	7,579	[3]	7,295	[3]
Depreciation, depletion and amortization										953		915		853
Interest income										7		8		6
Interest and related charges										443		411		369
Income tax expense										659		548		659
Net income (loss) attributable to Dominion		187	385	246	269	151	314	69	324	1,087		858		1,138
Capital expenditures										2,474		2,911		2,394
Capital expenditures										2,689		3,107		2,533
Total assets		31,622				29,509				31,622		29,509
Virginia Electric and Power Company | Adjustments & Eliminations
Segment Reporting Information [Line Items]
Operating Revenue										0		0		0
Depreciation, depletion and amortization										0		0		0
Interest income										0		0		0
Interest and related charges										$ (1)		0		0
Income tax expense												0		0
Net income (loss) attributable to Dominion										$ 0		0		0
Capital expenditures										0		0		0
Total assets		(100)				(100)				(100)		(100)
Virginia Electric and Power Company | DVP | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										2,099		1,928		1,826
Depreciation, depletion and amortization										498		462		427
Interest income										0		0		0
Interest and related charges										230		205		175
Income tax expense										308		317		286
Net income (loss) attributable to Dominion										490		509		483
Capital expenditures										1,569		1,651		1,360
Total assets		14,700				13,200				14,700		13,200
Virginia Electric and Power Company | Dominion Generation | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										5,566		5,651		5,475
Depreciation, depletion and amortization										453		416		425
Interest income										7		8		6
Interest and related charges										210		203		192
Income tax expense										437		416		399
Net income (loss) attributable to Dominion										750		691		702
Capital expenditures										1,120		1,456		1,173
Total assets		17,000				16,400				17,000		16,400
Virginia Electric and Power Company | Corporate and Other | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										(43)		0		(6)
Depreciation, depletion and amortization										2		37		1
Interest income										0		0		0
Interest and related charges										4		3		2
Income tax expense										(86)		(185)		(26)
Net income (loss) attributable to Dominion										(153)		(342)		(47)
Capital expenditures										0		0		0
Total assets		0				0				0		0
Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
Operating Revenue		425	365	395	531	510	391	428	569	1,716	[4]	1,898	[4]	1,937	[4]
Depreciation, depletion and amortization										217		197		188
Equity in earnings of equity method investees										23		21		22
Interest income										1		1		2
Interest and related charges										73		27		28
Income tax expense										283		334		301
Net income (loss) attributable to Dominion		100	$ 111	$ 85	$ 161	148	$ 107	$ 93	$ 164	457		512		461
Capital expenditures										795		719		650
Investment in equity method affiliates		102				107				102		107
Total assets		10,331				9,848				10,331		9,848
Dominion Gas Holdings, LLC | Dominion Energy | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										1,716		1,898		1,937
Depreciation, depletion and amortization										213		197		188
Equity in earnings of equity method investees										23		21		22
Interest income										1		1		2
Interest and related charges										72		27		28
Income tax expense										296		340		333
Net income (loss) attributable to Dominion										478		521		510
Capital expenditures										795		719		650
Investment in equity method affiliates		102				107				102		107
Total assets		9,700				9,200				9,700		9,200
Dominion Gas Holdings, LLC | Corporate and Other | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue										0		0		0
Depreciation, depletion and amortization										4		0		0
Equity in earnings of equity method investees										0		0		0
Interest income										0		0		0
Interest and related charges										1		0		0
Income tax expense										(13)		(6)		(32)
Net income (loss) attributable to Dominion										(21)		(9)		(49)
Capital expenditures										0		0		$ 0
Investment in equity method affiliates		0				0				0		0
Total assets		$ 600				$ 600				$ 600		$ 600
[1]	Includes income tax benefit of $43 million in 2013.
[2]	Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.
[3]	See Note 24 for amounts attributable to affiliates.
[4]	See Note 24 for amounts attributable to related parties.

Quarterly Financial and Comm138

Quarterly Financial and Common Stock Data (Unaudited) (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Mar. 31, 2014
Condensed Financial Statements, Captions [Line Items]
After tax charges associated with liability management exercise				$ 172
Charge recognized, net of tax					$ 191	$ 193
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
Virginia Electric and Power Company | Deferred Fuel Costs | Virginia Regulation
Condensed Financial Statements, Captions [Line Items]
Write off of deferred fuel cost, net of tax	$ 52
Virginia Electric and Power Company | Facilities Subject to Coal Combustion Residual Final Rule
Condensed Financial Statements, Captions [Line Items]
Charge related to settlement offer, net of tax	32		$ 28
Dominion Gas Holdings, LLC
Condensed Financial Statements, Captions [Line Items]
After tax gain from agreement to convey development rights				$ 36
Dominion Gas Holdings, LLC | Oil and Gas Properties
Condensed Financial Statements, Captions [Line Items]
After tax gain on sale	$ 43	$ 29

Quarterly Financial and Comm139

Quarterly Financial and Common Stock Data (Unaudited) (Quarterly Financial and Common Stock Data) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended																12 Months Ended
	Dec. 31, 2015		Sep. 30, 2015		Jun. 30, 2015		Mar. 31, 2015		Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Operating Revenue	$ 2,556		$ 2,971		$ 2,747		$ 3,409		$ 2,943		$ 3,050		$ 2,813		$ 3,630		$ 11,683		$ 12,436		$ 13,120
Income from operations	638		1,123		773		1,002		638		921		394		768		3,536		2,721		3,316
Net income including noncontrolling interests	366		599		418		540		249		531		161		385		1,923		1,326		1,720
Income from continuing operations	357	[1]	593	[1]	413	[1]	536	[1]	243	[1]	529	[1]	159	[1]	379	[1]	1,899	[1]	1,310	[1]	1,789
Net income (loss) attributable to Dominion	$ 357		$ 593		$ 413		$ 536		$ 243		$ 529		$ 159		$ 379		1,899		1,310		1,697
Net income including noncontrolling interests																	$ 1,923		$ 1,326		$ 1,720
Income from continuing operations - basic (in dollars per share)	$ 0.60	[1]	$ 1	[1]	$ 0.70	[1]	$ 0.91	[1]	$ 0.42	[1]	$ 0.91	[1]	$ 0.27	[1]	$ 0.65	[1]	$ 3.21	[1]	$ 2.25	[1]	$ 3.09
Net income attributable to Dominion (in dollars per share)	0.60		1		0.70		0.91		0.42		0.91		0.27		0.65		3.21		2.25		2.93
Income from continuing operations - diluted (in dollars per share)	0.60	[1]	1	[1]	0.70	[1]	0.91	[1]	0.42	[1]	0.90	[1]	0.27	[1]	0.65	[1]	3.20	[1]	2.24	[1]	3.09
Net income attributable to Dominion - diluted (in dollars per share)	0.60		1		0.70		0.91		0.42		0.90		0.27		0.65		3.20		2.24		2.93
Dividends declared per common share	$ 0.6475		$ 0.6475		$ 0.6475		$ 0.6475		$ 0.6		$ 0.6		$ 0.6		$ 0.6		$ 2.59		$ 2.40		$ 2.25
Virginia Electric and Power Company
Condensed Financial Statements, Captions [Line Items]
Operating Revenue	$ 1,614		$ 2,058		$ 1,813		$ 2,137		$ 1,814		$ 2,053		$ 1,729		$ 1,983		$ 7,622	[2]	$ 7,579	[2]	$ 7,295	[2]
Income from operations	374		741		481		525		312		594		205		613		2,121		1,724		2,080
Net income (loss) attributable to Dominion	187		385		246		269		151		314		69		324		1,087		858		1,138
Net income including noncontrolling interests	187		385		246		269		148		312		67		318		1,087		845		1,121
Dominion Gas Holdings, LLC
Condensed Financial Statements, Captions [Line Items]
Operating Revenue	425		365		395		531		510		391		428		569		1,716	[3]	1,898	[3]	1,937	[3]
Income from operations	163		202		153		271		255		177		154		265		789		851		762
Net income (loss) attributable to Dominion	$ 100		$ 111		$ 85		$ 161		$ 148		$ 107		$ 93		$ 164		$ 457		$ 512		$ 461
Maximum
Condensed Financial Statements, Captions [Line Items]
Share Price	$ 74.88		$ 76.59		$ 74.34		$ 79.89		$ 80.89		$ 71.62		$ 73.75		$ 72.22		$ 74.88		$ 80.89
Common stock market value (high)																	79.89		80.89
Minimum
Condensed Financial Statements, Captions [Line Items]
Share Price	$ 64.54		$ 66.65		$ 66.52		$ 68.25		$ 65.53		$ 64.71		$ 67.06		$ 63.14		64.54		65.53
Common stock market value (low)																	$ 64.54		$ 63.14
[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.